Kentucky Utilities 10-K 14 Feb 20 2019 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2019	Jan. 31, 2020
Document Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
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		767,813,625
Entity Public Float	$ 22,384,264,788
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 2020 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, 2019. Such Statements will provide the information required by Part III of this Report.
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	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		66,368,056
Amendment Flag	false
Entity Central Index Key	0000317187
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
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
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
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	VA

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Revenues
Operating Revenues		$ 7,769	$ 7,785	$ 7,447
Operation
Fuel		709	799	759
Energy purchases		723	745	685
Other operation and maintenance		1,985	1,983	1,802
Depreciation		1,199	1,094	1,008
Taxes, other than income		313	312	292
Total Operating Expenses		4,929	4,933	4,546
Operating Income		2,840	2,852	2,901
Other Income (Expense) - net		309	396	(88)
Interest Expense		994	963	901
Income Before Income Taxes		2,155	2,285	1,912
Income Taxes		409	458	784
Net income		$ 1,746	$ 1,827	$ 1,128
Net Income Available to PPL Common Shareowners
Basic (in dollars per share)		$ 2.39	$ 2.59	$ 1.64
Diluted (in dollars per share)		$ 2.37	$ 2.58	$ 1.64
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		728,512	704,439	685,240
Diluted		736,754	708,619	687,334
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 2,358	$ 2,277	$ 2,195
Operation
Energy purchases		549	544	507
Other operation and maintenance		566	578	572
Depreciation		386	352	309
Taxes, other than income		112	109	107
Total Operating Expenses		1,613	1,583	1,495
Operating Income		745	694	700
Other Income (Expense) - net		25	23	12
Interest Income from Affiliate		6	8	5
Interest Expense		170	159	142
Income Before Income Taxes		606	566	575
Income Taxes		149	136	213
Net income	[1]	457	430	362
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		3,206	3,214	3,156
Operation
Fuel		709	799	759
Energy purchases		174	201	178
Other operation and maintenance		861	848	801
Depreciation		547	475	439
Taxes, other than income		74	70	65
Total Operating Expenses		2,365	2,393	2,242
Operating Income		841	821	914
Other Income (Expense) - net		(13)	(16)	(8)
Interest Expense		226	206	197
Interest Expense with Affiliates		31	25	18
Income Before Income Taxes		571	574	691
Income Taxes		103	129	375
Net income		468	445	316
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		1,473	1,467	1,422
Electric revenue from affiliates		27	29	31
Operating Revenues		1,500	1,496	1,453
Operation
Fuel		289	308	292
Energy purchases		154	183	160
Energy purchases from affiliate		7	13	10
Other operation and maintenance		387	376	350
Depreciation		231	195	183
Taxes, other than income		39	36	33
Total Operating Expenses		1,107	1,111	1,028
Operating Income		393	385	425
Other Income (Expense) - net		(11)	(12)	(10)
Interest Expense		87	76	71
Income Before Income Taxes		295	297	344
Income Taxes		63	64	131
Net income	[2]	232	233	213
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		1,733	1,747	1,734
Electric revenue from affiliates		7	13	10
Operating Revenues		1,740	1,760	1,744
Operation
Fuel		420	491	467
Energy purchases		20	18	18
Energy purchases from affiliate		27	29	31
Other operation and maintenance		438	441	423
Depreciation		315	279	255
Taxes, other than income		35	34	32
Total Operating Expenses		1,255	1,292	1,226
Operating Income		485	468	518
Other Income (Expense) - net		(4)	(6)	(4)
Interest Expense		109	100	96
Income Before Income Taxes		372	362	418
Income Taxes		79	76	159
Net income	[3]	$ 293	$ 286	$ 259
[1]	Net income equals comprehensive income.
[2]	Net income equals comprehensive income.
[3]	Net income approximates comprehensive income.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Net income	$ 1,746	$ 1,827	$ 1,128
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	108	(444)	538
Qualifying derivatives, net of tax	(11)	36	(79)
Defined benefit plans:
Prior service costs, net of tax	(1)	(11)	0
Net actuarial gain (loss), net of tax	(592)	(187)	(308)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	13	(29)	73
Equity investees' other comprehensive (income) loss, net of tax	0	0	1
Defined benefit plans:
Prior service costs, net of tax	2	2	1
Net actuarial (gain) loss, net of tax	87	142	130
Total other comprehensive income (loss)	(394)	(491)	356
Comprehensive income	1,352	1,336	1,484
LG And E And KU Energy LLC [Member]
Net income	468	445	316
Defined benefit plans:
Prior service costs, net of tax	(1)	0	(2)
Net actuarial gain (loss), net of tax	(6)	7	(23)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax	0	0	1
Defined benefit plans:
Prior service costs, net of tax	1	2	1
Net actuarial (gain) loss, net of tax	2	8	5
Total other comprehensive income (loss)	(4)	17	(18)
Comprehensive income	$ 464	$ 462	$ 298

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Tax effect of foreign currency translation adjustments arising during the period	$ 0	$ (2)	$ (1)
Tax effect of qualifying derivatives arising during the period	2	(9)	19
Tax effect of defined benefit plans - prior service costs arising during period	0	3	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	119	44	72
Tax effect of equity investees' other comprehensive (income) loss reclassified from AOCI	0	0	0
Tax effect of qualifying derivatives reclassified from AOCI	5	(6)	18
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	(1)	0	(1)
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	(22)	(36)	(37)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - prior service costs arising during period	0	0	(1)
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	0	0	13
Tax effect of equity investees' other comprehensive (income) loss reclassified from AOCI	0	0	0
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	0	0	1
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	$ (1)	$ 5	$ 2

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Flows from Operating Activities
Net income		$ 1,746	$ 1,827	$ 1,128
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		1,199	1,094	1,008
Amortization		81	78	97
Defined benefit plans - expense (income)		(263)	(192)	(95)
Deferred income taxes and investment tax credits		309	355	707
Unrealized (gains) losses on derivatives, and other hedging activities		73	(186)	178
Stock compensation expense		36	26	38
Other		(22)	(3)	(9)
Change in current assets and current liabilities
Accounts receivable		4	28	(33)
Accounts payable		(77)	78	(10)
Unbilled Revenues		(5)	41	(48)
Fuel, materials and supplies		(26)	17	40
Regulatory assets and liabilities, net		(88)	13	(12)
Other current liabilities		(73)	(22)	6
Other		(33)	(2)	11
Other operating activities
Defined benefit plans - funding		(350)	(361)	(565)
Proceeds from transfer of excess benefit plan funds		0	65	0
Other assets		(100)	(75)	32
Other liabilities		16	40	(12)
Net cash provided by operating activities		2,427	2,821	2,461
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(3,083)	(3,238)	(3,133)
Purchases of investments		55	65	0
Proceeds from the sale of investments		69	6	0
Other investing activities		(11)	(64)	(28)
Net cash provided by (used in) investing activities		(3,080)	(3,361)	(3,161)
Cash Flows from Financing Activities
Issuance of long-term debt		1,465	1,059	1,515
Retirement of long-term debt		(300)	(277)	(168)
Issuance of common stock		1,167	698	453
Payment of common stock dividends		(1,192)	(1,133)	(1,072)
Net increase (decrease) in short-term debt		(278)	363	115
Other financing activities		(26)	(20)	(19)
Net cash provided by (used in) financing activities		836	690	824
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash		10	(18)	15
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		193	132	139
Cash and Cash Equivalents at Beginning of Period		621
Cash and Cash Equivalents at End of Period		815	621
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		643	511	372
Cash, Cash Equivalents and Restricted Cash at End of Period		836	643	511
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		905	910	845
Income taxes - net		93	127	65
Accrued expenditures for property, plant and equipment at December 31,		340	345	360
Accrued expenditures for intangible assets at December 31,		79	64	68
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income	[1]	457	430	362
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		386	352	309
Amortization		24	22	33
Defined benefit plans - expense (income)		0	3	12
Deferred income taxes and investment tax credits		90	125	258
Other		(19)	(4)	(8)
Change in current assets and current liabilities
Accounts receivable		33	47	(57)
Accounts payable		5	10	3
Unbilled Revenues		(14)	7	(13)
Prepayments		(1)	1	3
Taxes payable		1	4	(4)
Regulatory assets and liabilities, net		(43)	(19)	(5)
Other		(11)	10	(1)
Other operating activities
Defined benefit plans - funding		(21)	(28)	(24)
Other assets		15	(37)	15
Other liabilities		11	55	(3)
Net cash provided by operating activities		913	978	880
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,114)	(1,192)	(1,244)
Expenditures for intangible assets		(7)	(4)	(10)
Other investing activities		4	3	2
Net cash provided by (used in) investing activities		(1,117)	(1,193)	(1,252)
Cash Flows from Financing Activities
Issuance of long-term debt		393	398	470
Retirement of long-term debt		(100)	0	0
Contributions from parent		400	429	575
Payment of common stock dividends to parent		(486)	(390)	(336)
Net increase (decrease) in short-term debt			0	(295)
Other financing activities		(8)	(4)	(6)
Net cash provided by (used in) financing activities		199	433	408
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(5)	218	36
Cash and Cash Equivalents at Beginning of Period		267
Cash and Cash Equivalents at End of Period		262	267
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		269	51	15
Cash, Cash Equivalents and Restricted Cash at End of Period		264	269	51
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		154	144	128
Income taxes - net		32	(20)	4
Accrued expenditures for property, plant and equipment at December 31,		180	158	133
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net income		468	445	316
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		547	475	439
Amortization		27	18	24
Defined benefit plans - expense (income)		11	17	25
Deferred income taxes and investment tax credits		82	94	294
Other		(3)	(4)	0
Change in current assets and current liabilities
Accounts receivable		(16)	1	(12)
Accounts payable		(26)	39	(9)
Unbilled Revenues		5	34	(33)
Accounts payable to affiliates		2	2	2
Fuel, materials and supplies		0	7	45
Taxes payable		(5)	(3)	27
Regulatory assets and liabilities, net		(45)	32	(7)
Other		(8)	(24)	41
Other operating activities
Defined benefit plans - funding		(34)	(131)	(35)
Other assets		(3)	(24)	8
Expenditures for asset retirement obligations		(89)	(72)	(34)
Other liabilities		25	9	8
Net cash provided by operating activities		938	915	1,099
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,094)	(1,117)	(892)
Other investing activities		0	1	4
Net cash provided by (used in) investing activities		(1,094)	(1,116)	(888)
Cash Flows from Financing Activities
Issuance of long-term debt		705	118	160
Issuance of long-term note with affiliate		0	250	0
Retirement of long-term debt		(200)	(27)	(70)
Acquisition of outstanding bonds		(40)	0	0
Remarketing of reacquired bonds		40	0	0
Contributions from member		63	0	0
Distributions to member		(308)	(302)	(402)
Net increase (decrease) in notes payable to affiliates		37	(112)	62
Net increase (decrease) in short-term debt		(126)	270	59
Other financing activities		(12)	(2)	(3)
Net cash provided by (used in) financing activities		159	195	(194)
Net Increase (Decrease) in Cash and Cash Equivalents		3	(6)	17
Cash and Cash Equivalents at Beginning of Period		24	30	13
Cash and Cash Equivalents at End of Period		27	24	30
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		237	218	204
Income taxes - net		29	46	48
Accrued expenditures for property, plant and equipment at December 31,		113	150	174
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income	[2]	232	233	213
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		231	195	183
Amortization		15	14	14
Defined benefit plans - expense (income)		3	3	7
Deferred income taxes and investment tax credits		56	60	126
Other		0	0	1
Change in current assets and current liabilities
Accounts receivable		(9)	4	(7)
Accounts receivable from affiliates		6	0	4
Accounts payable		(10)	10	(7)
Unbilled Revenues		1	14	(16)
Accounts payable to affiliates		5	1	(4)
Fuel, materials and supplies		5	4	12
Taxes payable		7	1	(15)
Regulatory assets and liabilities, net		(19)	5	(5)
Other		(5)	(10)	16
Other operating activities
Defined benefit plans - funding		(6)	(61)	(4)
Other assets		(1)	(12)	5
Expenditures for asset retirement obligations		(30)	(22)	(15)
Other liabilities		11	4	4
Net cash provided by operating activities		492	443	512
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(482)	(554)	(458)
Net cash provided by (used in) investing activities		(482)	(554)	(458)
Cash Flows from Financing Activities
Issuance of long-term debt		399	100	160
Retirement of long-term debt		(200)	0	(70)
Acquisition of outstanding bonds		(40)	0	0
Remarketing of reacquired bonds		40	0	0
Contributions from parent		25	83	30
Payment of common stock dividends to parent		(182)	(156)	(192)
Net increase (decrease) in short-term debt		(41)	80	30
Other financing activities		(6)	(1)	(2)
Net cash provided by (used in) financing activities		(5)	106	(44)
Net Increase (Decrease) in Cash and Cash Equivalents		5	(5)	10
Cash and Cash Equivalents at Beginning of Period		10	15	5
Cash and Cash Equivalents at End of Period		15	10	15
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		77	71	65
Income taxes - net		2	7	22
Accrued expenditures for property, plant and equipment at December 31,		59	61	92
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income	[3]	293	286	259
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		315	279	255
Amortization		10	3	9
Defined benefit plans - expense (income)		(1)	0	4
Deferred income taxes and investment tax credits		39	48	152
Other		(3)	(4)	0
Change in current assets and current liabilities
Accounts receivable		(3)	(4)	(5)
Accounts payable		(15)	29	0
Unbilled Revenues		4	20	(17)
Accounts payable to affiliates		(2)	(3)	(6)
Fuel, materials and supplies		(6)	3	32
Taxes payable		2	5	(26)
Regulatory assets and liabilities, net		(26)	27	(2)
Other		(6)	(3)	9
Other operating activities
Defined benefit plans - funding		(3)	(54)	(23)
Other assets		(2)	(12)	3
Expenditures for asset retirement obligations		(59)	(50)	(19)
Other liabilities		16	11	9
Net cash provided by operating activities		553	581	634
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(610)	(562)	(432)
Other investing activities		0	1	4
Net cash provided by (used in) investing activities		(610)	(561)	(428)
Cash Flows from Financing Activities
Issuance of long-term debt		306	18	0
Retirement of long-term debt		0	(27)	0
Contributions from parent		68	45	0
Payment of common stock dividends to parent		(229)	(246)	(226)
Net increase (decrease) in short-term debt		(85)	190	29
Other financing activities		(5)	(1)	(1)
Net cash provided by (used in) financing activities		55	(21)	(198)
Net Increase (Decrease) in Cash and Cash Equivalents		(2)	(1)	8
Cash and Cash Equivalents at Beginning of Period		14	15	7
Cash and Cash Equivalents at End of Period		12	14	15
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		101	95	92
Income taxes - net		39	25	34
Accrued expenditures for property, plant and equipment at December 31,		$ 54	$ 88	$ 82
[1]	Net income equals comprehensive income.
[2]	Net income equals comprehensive income.
[3]	Net income approximates comprehensive income.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions		Dec. 31, 2019	Dec. 31, 2018
Current Assets
Cash and cash equivalents		$ 815	$ 621
Accounts receivable (less reserve:)
Customer		687	663
Other		105	107
Unbilled revenues		504	496
Fuel, materials and supplies		332	303
Prepayments		79	70
Price risk management assets		147	109
Regulatory assets		67	36
Other current assets		98	63
Total Current Assets		2,767	2,432
Property, Plant and Equipment
Regulated utility plant		42,709	39,734
Less: accumulated depreciation - regulated utility plant		8,055	7,310
Regulated utility plant, net		34,654	32,424
Non-regulated property, plant and equipment		357	355
Less: accumulated depreciation - non-regulated property, plant and equipment		109	101
Non-regulated property, plant and equipment, net		248	254
Construction work in progress		1,580	1,780
Property, Plant and Equipment, net		36,482	34,458
Other Noncurrent Assets
Regulatory assets		1,492	1,673
Goodwill		3,198	3,162
Other intangibles		742	716
Pension benefit asset		464	535
Price risk management assets		149	228
Other noncurrent assets		386	192
Total Other Noncurrent Assets		6,431	6,506
Total Assets		45,680	43,396
Current Liabilities
Short-term debt		1,151	1,430
Long-term debt due within one year		1,172	530
Accounts payable		956	989
Taxes		99	110
Interest		294	278
Dividends		317	296
Customer deposits		261	257
Regulatory liabilities		115	122
Other current liabilities		535	551
Total Current Liabilities		4,900	4,563
Long-term Debt [Abstract]
Long-term Debt		20,721	20,069
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,088	2,796
Investment tax credits		124	126
Accrued pension obligations		587	771
Asset retirement obligations		212	264
Regulatory liabilities		2,572	2,714
Other deferred credits and noncurrent liabilities		485	436
Total Deferred Credits and Other Noncurrent Liabilities		7,068	7,107
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	7
Additional paid-in capital		12,214	11,021
Earnings reinvested		5,127	4,593
Accumulated other comprehensive loss		(4,358)	(3,964)
Total Equity		12,991	11,657
Total Liabilities and Equity		45,680	43,396
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		262	267
Accounts receivable (less reserve:)
Customer		258	264
Other		22	38
Accounts receivable from affiliates		11	11
Unbilled revenues		134	120
Fuel, materials and supplies		33	25
Prepayments		6	5
Regulatory assets		26	11
Other current assets		9	9
Total Current Assets		761	750
Property, Plant and Equipment
Regulated utility plant		12,589	11,637
Less: accumulated depreciation - regulated utility plant		3,078	2,856
Regulated utility plant, net		9,511	8,781
Construction work in progress		597	586
Property, Plant and Equipment, net		10,108	9,367
Other Noncurrent Assets
Regulatory assets		726	824
Other intangibles		263	260
Other noncurrent assets		43	42
Total Other Noncurrent Assets		1,032	1,126
Total Assets		11,901	11,243
Current Liabilities
Long-term debt due within one year		0	0
Accounts payable		438	418
Accounts payable to affiliates		32	25
Taxes		13	12
Interest		41	37
Regulatory liabilities		96	74
Other current liabilities		93	101
Total Current Liabilities		713	667
Long-term Debt [Abstract]
Long-term Debt		3,985	3,694
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,447	1,320
Accrued pension obligations		179	282
Regulatory liabilities		599	675
Other deferred credits and noncurrent liabilities		146	144
Total Deferred Credits and Other Noncurrent Liabilities		2,371	2,421
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		3,558	3,158
Earnings reinvested		910	939
Total Equity		4,832	4,461
Total Liabilities and Equity		11,901	11,243
LG And E And KU Energy LLC [Member]
Current Assets
Cash and cash equivalents		27	24
Accounts receivable (less reserve:)
Customer		260	239
Other		71	63
Unbilled revenues		164	169
Fuel, materials and supplies		250	248
Prepayments		30	25
Regulatory assets		41	25
Other current assets		2	0
Total Current Assets		845	793
Property, Plant and Equipment
Regulated utility plant		14,646	13,721
Less: accumulated depreciation - regulated utility plant		2,356	2,125
Regulated utility plant, net		12,290	11,596
Construction work in progress		794	1,018
Property, Plant and Equipment, net		13,084	12,614
Other Noncurrent Assets
Regulatory assets		766	849
Goodwill		996	996
Other intangibles		69	78
Other noncurrent assets		171	82
Total Other Noncurrent Assets		2,002	2,005
Total Assets		15,931	15,412
Current Liabilities
Short-term debt		388	514
Long-term debt due within one year		975	530
Notes payable with affiliates		150	113
Accounts payable		316	366
Accounts payable to affiliates		11	9
Taxes		58	63
Interest		40	32
Asset Retirement Obligations		70	82
Price risk management liabilities		4	4
Customer deposits		62	61
Regulatory liabilities		19	48
Other current liabilities		153	126
Total Current Liabilities		2,246	1,948
Long-term Debt [Abstract]
Long-term debt		4,377	4,322
Long-term debt to affiliate		650	650
Long-term Debt		5,027	4,972
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,069	956
Investment tax credits		124	126
Price risk management liabilities		17	16
Accrued pension obligations		233	282
Asset retirement obligations		145	214
Regulatory liabilities		1,973	2,039
Other deferred credits and noncurrent liabilities		155	136
Total Deferred Credits and Other Noncurrent Liabilities		3,716	3,769
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(93)	(89)
Member's Equity		4,942	4,723
Total Liabilities and Equity		15,931	15,412
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		15	10
Accounts receivable (less reserve:)
Customer		121	110
Other		41	30
Accounts receivable from affiliates		18	24
Unbilled revenues		76	77
Fuel, materials and supplies		122	127
Prepayments		14	12
Regulatory assets		25	21
Other current assets		1	0
Total Current Assets		433	411
Property, Plant and Equipment
Regulated utility plant		6,372	5,816
Less: accumulated depreciation - regulated utility plant		846	741
Regulated utility plant, net		5,526	5,075
Construction work in progress		297	514
Property, Plant and Equipment, net		5,823	5,589
Other Noncurrent Assets
Regulatory assets		380	431
Goodwill		389	389
Other intangibles		41	47
Other noncurrent assets		67	16
Total Other Noncurrent Assets		877	883
Total Assets		7,133	6,883
Current Liabilities
Short-term debt		238	279
Long-term debt due within one year		0	434
Accounts payable		172	172
Accounts payable to affiliates		31	26
Taxes		33	26
Interest		15	11
Asset Retirement Obligations		24	23
Price risk management liabilities		4	4
Customer deposits		31	29
Regulatory liabilities		2	17
Other current liabilities		47	39
Total Current Liabilities		597	1,060
Long-term Debt [Abstract]
Long-term Debt		2,005	1,375
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		697	628
Investment tax credits		34	34
Price risk management liabilities		17	16
Asset retirement obligations		49	80
Regulatory liabilities		883	915
Other deferred credits and noncurrent liabilities		89	88
Total Deferred Credits and Other Noncurrent Liabilities		1,769	1,761
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,820	1,795
Earnings reinvested		518	468
Total Equity		2,762	2,687
Total Liabilities and Equity		7,133	6,883
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		12	14
Accounts receivable (less reserve:)
Customer		139	129
Other		27	34
Unbilled revenues		88	92
Fuel, materials and supplies		128	121
Prepayments		14	11
Regulatory assets		16	4
Other current assets		1	0
Total Current Assets		425	405
Property, Plant and Equipment
Regulated utility plant		8,262	7,895
Less: accumulated depreciation - regulated utility plant		1,507	1,382
Regulated utility plant, net		6,755	6,513
Construction work in progress		496	503
Property, Plant and Equipment, net		7,251	7,016
Other Noncurrent Assets
Regulatory assets		386	418
Goodwill		607	607
Other intangibles		28	31
Other noncurrent assets		128	63
Total Other Noncurrent Assets		1,149	1,119
Total Assets		8,825	8,540
Current Liabilities
Short-term debt		150	235
Long-term debt due within one year		500	96
Accounts payable		121	171
Accounts payable to affiliates		52	53
Taxes		26	24
Interest		20	16
Asset Retirement Obligations		46	59
Customer deposits		31	32
Regulatory liabilities		17	31
Other current liabilities		51	35
Total Current Liabilities		1,014	752
Long-term Debt [Abstract]
Long-term Debt		2,123	2,225
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		792	735
Investment tax credits		90	92
Asset retirement obligations		96	134
Regulatory liabilities		1,090	1,124
Other deferred credits and noncurrent liabilities		46	36
Total Deferred Credits and Other Noncurrent Liabilities		2,114	2,121
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,729	2,661
Earnings reinvested		537	473
Total Equity		3,574	3,442
Total Liabilities and Equity		$ 8,825	$ 8,540
[1]	1,560,000 shares authorized; 767,233 and 720,323 shares issued and outstanding at December 31, 2019 and December 31, 2018 .
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2019 and December 31, 2018
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2019 and December 31, 2018 .
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2019 and December 31, 2018 .

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 58	$ 56
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	1,560,000	1,560,000
Common stock shares issued	767,233	720,323
Common stock shares outstanding	767,233	720,323
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 28	$ 27
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	$ 28	$ 27
Louisville Gas And Electric Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 1	$ 1
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	75,000	75,000
Common stock shares issued	21,294	21,294
Common stock shares outstanding	21,294	21,294
Kentucky Utilities Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 1	$ 2
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	Common Stock [Member]		Additional Paid-in Capital	Earnings Reinvested	Accumulated Other Comprehensive Loss	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		$ 1.58
Balance at beginning of period - shares at Dec. 31, 2016			679,731	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2016														$ 4,667
Balance at beginning of period at Dec. 31, 2016		$ 9,899	$ 7		$ 9,841	$ 3,829	$ (3,778)	$ 3,391		$ 364		$ 2,154	$ 873		$ 2,476		$ 424		$ 1,682	$ 370	$ 3,323		$ 308		$ 2,616	$ 400	$ (1)
Common stock shares issued	[1]		13,667
Common stock issued		482			482
Stock-based compensation		(18)			(18)
Net income		1,128				1,128		362	[5]				362	316	213	[6]				213	259	[7]				259
Capital contributions from parent								575				575			30				30
Dividends and dividend equivalents		(1,086)				(1,086)
Cash dividends declared on common stock								(336)					(336)		(192)					(192)	(226)					(226)
Distributions to member														(402)
Other comprehensive income (loss)		356					356							(18)							1						1
Balance at end of period - shares at Dec. 31, 2017			693,398	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2017														4,563
Balance at end 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
Dividends Declared Per Share of Common Stock		$ 1.64
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	720,323	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		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
Cumulative Effect of New Accounting Principle in Period of Adoption		$ 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
[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 approximates comprehensive income.

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) $ in Millions	12 Months Ended
	Dec. 31, 2019vote	Dec. 31, 2018vote	Dec. 31, 2017USD ($)vote
Vote per share of PPL's common stock | vote	1	1	1
PPL Electric Utilities Corp [Member]
Non-cash contributions related to remeasurement and separation of benefit plans | $			$ 56

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
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 indirect, 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. The Registrants are not the primary beneficiary in any significant VIEs. 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 12 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. (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 16 and 17 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 kWh by an average rate per customer class. 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 regulatory years later. This revenue change is called the "TRU" adjustment. • 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-year lag from the time they are earned and/or assessed. Incentive revenues and penalties are included in revenues when they are billed to customers. • 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 year lag. Accounts Receivable (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Allowance for Doubtful Accounts Accounts 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. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. The changes in the allowance for doubtful accounts were: Additions Balance at Beginning of Period Charged to Income Charged to Other Accounts Deductions (a) Balance at End of Period PPL 2019 $ 56 $ 37 $ 3 $ 38 $ 58 2018 51 41 3 39 56 2017 54 28 (1 ) 30 51 PPL Electric 2019 $ 27 $ 26 $ — $ 25 $ 28 2018 24 29 — 26 27 2017 28 18 — 22 24 LKE 2019 $ 27 $ 8 $ 3 $ 10 $ 28 2018 25 10 3 11 27 2017 24 8 (1 ) 6 25 LG&E 2019 $ 1 $ 2 $ 2 $ 4 $ 1 2018 1 4 1 5 1 2017 2 2 (1 ) 2 1 KU 2019 $ 2 $ 4 $ 1 $ 6 $ 1 2018 1 5 2 6 2 2017 2 4 (1 ) 4 1 (a) Primarily related to uncollectible accounts written off. 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 that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL PPL Electric December 31, December 31, December 31, December 31, Cash and cash equivalents $ 815 $ 621 $ 262 $ 267 Restricted cash - current 3 3 2 2 Restricted cash - noncurrent (a) 18 19 — — Total Cash, Cash Equivalents and Restricted Cash $ 836 $ 643 $ 264 $ 269 (a) Primarily consists of funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment. (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 $10 million in 2019 , $15 million in 2018 and $11 million 2017 . 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: 2019 2018 2017 PPL 2.84 % 2.77 % 2.65 % PPL Electric 3.05 % 3.01 % 2.86 % LKE 3.96 % 3.69 % 3.64 % LG&E 3.87 % 3.63 % 3.63 % KU 4.02 % 3.74 % 3.66 % (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 two-step 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 two-step 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, the implied fair value of goodwill must be calculated in the same manner as goodwill in a business combination. The fair value of a reporting unit is allocated to all assets and liabilities of that unit as if the reporting unit had been acquired in a business combination. The excess of the fair value of the reporting unit over the amounts assigned to its assets and liabilities is the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, goodwill is written down to its implied fair value. PPL elected to bypass the qualitative step zero evaluation of goodwill and quantitatively tested the goodwill at its WPD reporting unit while LKE, LG&E and KU qualitatively tested the goodwill of its reporting units for impairment as of the fourth quarter of 2019. No impairment was recognized. ( 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 19 for additional information on AROs. Compensation and Benefits Defined Benefits (All Registrants) Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value. PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the required amortization period. Actuarial gains and losses in excess of 10% of the greater of the plan's pro

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2019
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 of 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: 2019 2018 2017 Operating Revenues from external customers (a) U.K. Regulated $ 2,167 $ 2,268 $ 2,091 Kentucky Regulated 3,206 3,214 3,156 Pennsylvania Regulated 2,358 2,277 2,195 Corporate and Other 38 26 5 Total $ 7,769 $ 7,785 $ 7,447 Depreciation U.K. Regulated $ 250 $ 247 $ 230 Kentucky Regulated 547 475 439 Pennsylvania Regulated 386 352 309 Corporate and Other 16 20 30 Total $ 1,199 $ 1,094 $ 1,008 Amortization (b) U.K. Regulated $ 25 $ 34 $ 34 Kentucky Regulated 27 18 24 Pennsylvania Regulated 24 22 33 Corporate and Other 5 4 6 Total $ 81 $ 78 $ 97 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ 62 $ (190 ) $ 166 Kentucky Regulated 6 6 6 Corporate and Other 5 (2 ) 6 Total $ 73 $ (186 ) $ 178 Interest Expense U.K. Regulated $ 405 $ 413 $ 397 Kentucky Regulated 298 274 261 Pennsylvania Regulated 169 159 142 Corporate and Other 122 117 101 Total $ 994 $ 963 $ 901 Income Before Income Taxes U.K. Regulated $ 1,169 $ 1,339 $ 804 Kentucky Regulated 530 531 645 Pennsylvania Regulated 607 567 575 Corporate and Other (151 ) (152 ) (112 ) Total $ 2,155 $ 2,285 $ 1,912 Income Taxes (d) U.K. Regulated $ 192 $ 225 $ 152 Kentucky Regulated 94 120 359 Pennsylvania Regulated 149 136 216 Corporate and Other (26 ) (23 ) 57 Total $ 409 $ 458 $ 784 Deferred income taxes and investment tax credits (e) U.K. Regulated $ 140 $ 118 $ 66 Kentucky Regulated 82 94 294 Pennsylvania Regulated 90 125 257 Corporate and Other (3 ) 18 90 Total $ 309 $ 355 $ 707 2019 2018 2017 Net Income U.K. Regulated $ 977 $ 1,114 $ 652 Kentucky Regulated 436 411 286 Pennsylvania Regulated 458 431 359 Corporate and Other (125 ) (129 ) (169 ) Total $ 1,746 $ 1,827 $ 1,128 (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 17 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 and 2017. (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: 2019 2018 2017 Expenditures for long-lived assets U.K. Regulated $ 857 $ 954 $ 1,015 Kentucky Regulated 1,097 1,117 892 Pennsylvania Regulated 1,121 1,196 1,254 Corporate and Other 32 1 10 Total $ 3,107 $ 3,268 $ 3,171 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2019 2018 Total Assets U.K. Regulated (a) $ 17,622 $ 16,700 Kentucky Regulated 15,597 15,078 Pennsylvania Regulated 11,918 11,257 Corporate and Other (b) 543 361 Total $ 45,680 $ 43,396 (a) Includes $13.2 billion and $12.4 billion of net PP&E as of December 31, 2019 and December 31, 2018 . 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: 2019 2018 2017 Revenues from external customers U.K. $ 2,167 $ 2,268 $ 2,091 U.S. 5,602 5,517 5,356 Total $ 7,769 $ 7,785 $ 7,447 As of December 31, 2019 2018 Long-Lived Assets U.K. $ 13,618 $ 12,791 U.S. 23,607 22,384 Total $ 37,225 $ 35,175 (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, 2019
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 a per-unit of energy 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 per-unit of energy tariff rate 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: 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, 2019 and 2018 , PPL includes $2.2 billion and $2.3 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: 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 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's segments are segmented by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the table above. For PPL Electric, revenues from contracts with customers are further disaggregated by distribution and transmission, which were $1.7 billion and $594 million for the year ended December 31, 2019 and $1.9 billion and $405 million for the year ended December 31, 2018 . Contract receivables from customers are primarily included in "Accounts receivable - Customer" and "Unbilled revenues" on the Balance Sheets. For PPL Electric, the "Accounts receivable - Customer" balance includes purchased receivables from alternative electricity suppliers. See Note 7 for additional information regarding the purchase of receivables program. The following table shows the accounts receivable balances from contracts with customers that were impaired for the year ended December 31: 2019 2018 PPL $ 27 $ 34 PPL Electric 21 24 LKE 6 9 LG&E 2 4 KU 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, 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, 2019 , PPL had $36 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $32 million within the next 12 months .

Preferred Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2019
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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 .
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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 .
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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 .
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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 . (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 2019 , 2018 or 2017 .

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2019
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. See Note 8 for additional information on these 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: 2019 2018 2017 Income (Numerator) Net income $ 1,746 $ 1,827 $ 1,128 Less amounts allocated to participating securities 1 2 2 Net income available to PPL common shareowners - Basic and Diluted $ 1,745 $ 1,825 $ 1,126 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 728,512 704,439 685,240 Add incremental non-participating securities: Share-based payment awards (a) 1,101 445 2,094 Forward sale agreements 7,141 3,735 — Weighted-average shares - Diluted EPS 736,754 708,619 687,334 Basic EPS Net Income available to PPL common shareowners $ 2.39 $ 2.59 $ 1.64 Diluted EPS Net Income available to PPL common shareowners $ 2.37 $ 2.58 $ 1.64 (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): 2019 Stock-based compensation plans (a) 1,936 DRIP 1,725 (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 ATM Program and settlement of a portion of the PPL common stock forward sales agreements. 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: 2019 2018 2017 Stock options — 172 696 Performance units 5 — — Restricted stock units 3 11 —

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income and Other Taxes	(PPL) "Income Before Income Taxes" included the following: 2019 2018 2017 Domestic income $ 964 $ 1,127 $ 874 Foreign income 1,191 1,158 1,038 Total $ 2,155 $ 2,285 $ 1,912 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: 2019 2018 Deferred Tax Assets Deferred investment tax credits $ 31 $ 31 Regulatory liabilities 75 87 Income taxes due to customer 462 479 Accrued pension and postretirement costs 211 277 Federal loss carryforwards 324 325 State loss carryforwards 432 419 Federal and state tax credit carryforwards 402 392 Foreign capital loss carryforwards 320 313 Foreign - other 8 10 Contributions in aid of construction 112 139 Domestic - other 99 88 Valuation allowances (834 ) (808 ) Total deferred tax assets 1,642 1,752 Deferred Tax Liabilities Domestic plant - net 3,546 3,359 Regulatory assets 262 314 Foreign plant - net 765 724 Foreign - pensions 72 83 Domestic - other 61 40 Total deferred tax liabilities 4,706 4,520 Net deferred tax liability $ 3,064 $ 2,768 State deferred taxes are determined by entity and by jurisdiction. As a result, $24 million and $28 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 2019 and 2018 . At December 31, 2019 , 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 carryforwards Federal net operating losses $ 1,499 $ 315 $ — 2032-2037 Federal charitable contributions 42 9 — 2020-2024 State net operating losses 5,879 432 (393 ) 2021-2039 State charitable contributions 1 — — 2020-2024 Foreign net operating losses 3 — — Indefinite Foreign capital losses 1,880 320 (320 ) Indefinite Federal - Other 7 1 — Indefinite Credit carryforwards Federal investment tax credit 133 — 2025-2039 Federal alternative minimum tax credit (a) 8 — Indefinite Federal foreign tax credits (b) 218 (113 ) 2024-2027 Federal - other 24 (6 ) 2020-2039 State Recycling Credit 18 — 2028 State - other 1 — Indefinite (a) The TCJA repealed the corporate alternative minimum tax (AMT) for tax years beginning after December 31, 2017. The existing indefinite carryforward period for AMT credits was retained. (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 Beginning of Period Charged to Income Charged to Other Accounts Deductions Balance at End of Period 2019 $ 808 $ 31 $ — $ 5 $ 834 2018 838 26 — 56 (a) 808 2017 593 256 (b) — 11 838 (a) 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. (b) Increase in valuation allowance of approximately $145 million related to expected future utilization of both 2017 foreign tax credits and pre-2017 foreign tax credits carried forward. For additional information, see the "Reconciliation of Income Tax Expense" and associated notes below. In addition, the reduction of the U.S. federal corporate income tax rate enacted by the TCJA in 2017 resulted in a $62 million increase in federal deferred tax assets and a corresponding valuation allowance related to the federal tax benefits of state net operating losses. PPL Global does not record U.S. income taxes on the 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, 2019 was $7.5 billion . The foregoing is not impacted by U.S. tax reform and the associated conversion from a worldwide to a participation exemption system. 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. 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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ (10 ) $ (19 ) $ 6 Current - State 19 17 25 Current - Foreign 91 104 45 Total Current Expense (Benefit) 100 102 76 Deferred - Federal (a) 139 203 532 Deferred - State 76 100 88 Deferred - Foreign 123 107 133 Total Deferred Expense (Benefit), excluding operating loss carryforwards 338 410 753 Amortization of investment tax credit (3 ) (3 ) (3 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 7 (20 ) (16 ) Deferred - State (33 ) (31 ) (26 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards (26 ) (51 ) (42 ) Total income tax expense (benefit) $ 409 $ 458 $ 784 Total income tax expense (benefit) - Federal $ 133 $ 161 $ 519 Total income tax expense (benefit) - State 62 86 87 Total income tax expense (benefit) - Foreign 214 211 178 Total income tax expense (benefit) $ 409 $ 458 $ 784 (a) Due to the enactment of the TCJA, PPL recorded the following in 2017: • $220 million of deferred income tax expense related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities; • $162 million of deferred tax expense related to the utilization of current year losses resulting from the taxable deemed dividend; partially offset by, $60 million of deferred tax benefits related to the $205 million of 2017 foreign tax credits partially offset by $145 million of valuation allowances. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2019 2018 2017 Other comprehensive income $ (93 ) $ (6 ) $ (34 ) Valuation allowance on state deferred taxes recorded to other comprehensive income — — (1 ) Total $ (93 ) $ (6 ) $ (35 ) 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 453 $ 480 $ 669 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 45 40 46 Valuation allowance adjustments (b) 22 21 36 Impact of lower U.K. income tax rates (c) (25 ) (25 ) (176 ) U.S. income tax on foreign earnings - net of foreign tax credit (a)(d) 2 3 47 Foreign income return adjustments — — (8 ) Impact of the U.K. Finance Act on deferred tax balances (e) (14 ) (13 ) (16 ) Depreciation and other items not normalized (10 ) (11 ) (10 ) Amortization of excess deferred federal and state income taxes (f) (40 ) (37 ) — Interest benefit on U.K. financing entities (12 ) (17 ) (16 ) Deferred tax impact of U.S. tax reform (g) — — 220 Deferred tax impact of Kentucky tax reform (h) — 9 — Kentucky recycling credit, net of federal income tax expense (i) (18 ) — — Other 6 8 (8 ) Total increase (decrease) (44 ) (22 ) 115 Total income tax expense (benefit) $ 409 $ 458 $ 784 Effective income tax rate 19.0 % 20.0 % 41.0 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 2017, PPL recorded an increase in valuation allowances of $23 million primarily related to foreign tax credits recorded in 2016. The future utilization of these credits is expected to be lower as a result of the TCJA. In 2019, 2018 and 2017, PPL recorded deferred income tax expense of $25 million , $24 million and $16 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (c) The reduction in the U.S. federal corporate income tax rate from 35% to 21% significantly reduced the difference between the U.K. and U.S. income tax rates in 2019 and 2018 compared with 2017. (d) In 2017, PPL recorded a federal income tax benefit of $35 million primarily attributable to U.K. pension contributions. In 2017, PPL recorded deferred income tax expense of $83 million primarily related to enactment of the TCJA. The enacted tax law included a conversion from a worldwide tax system to a territorial tax system, effective January 1, 2018. In the transition to the territorial regime, a one-time transition tax was imposed on PPL’s unrepatriated accumulated foreign earnings in 2017. These earnings were treated as a taxable deemed dividend to PPL of approximately $462 million , including $205 million of foreign tax credits. As the PPL consolidated U.S. group had a taxable loss for 2017, inclusive of the taxable deemed dividend, these credits were recorded as a deferred tax asset. However, it is expected that under the TCJA, only $83 million of the $205 million of foreign tax credits will be realized in the carry forward period. Accordingly, a valuation allowance on the current year foreign tax credits in the amount of $122 million has been recorded to reflect the reduction in the future utilization of the credits. The foreign tax credits associated with the deemed repatriation result in a gross carryforward and corresponding deferred tax asset of $205 million offset by a valuation allowance of $122 million . (e) The U.K. Finance Act 2016, enacted in September 2016, reduced the U.K. statutory income tax rate effective April 1, 2020 to 17%. As a result, PPL reduced its net deferred tax liabilities each year as it revalued its balances at the 17% tax rate. (f) In 2019 and 2018, PPL recorded lower income tax expense for the amortization of excess deferred income 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. (g) In 2017, PPL recorded deferred income tax expense related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. 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. (h) 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, with the benefit recognized during the period in which the assets are placed into service. (i) In 2018, PPL filed its consolidated federal income tax return, which included updates to the TCJA provisional amounts recorded in 2017. The adjustments to the various provisional amounts that are considered complete as of the filed tax return resulted in an immaterial impact to income tax expense and are discussed in the TCJA section below. 2019 2018 2017 Taxes, other than income State gross receipts $ 107 $ 103 $ 102 State capital stock — — (6 ) Foreign property 127 134 127 Domestic Other 79 75 69 Total $ 313 $ 312 $ 292 (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: 2019 2018 Deferred Tax Assets Accrued pension and postretirement costs $ 81 $ 110 Contributions in aid of construction 88 118 Regulatory liabilities 31 35 Income taxes due to customers 170 181 State loss carryforwards 6 14 Federal loss carryforwards 78 79 Other 23 25 Total deferred tax assets 477 562 2019 2018 Deferred Tax Liabilities Electric utility plant - net 1,761 1,681 Regulatory assets 139 176 Other 24 25 Total deferred tax liabilities 1,924 1,882 Net deferred tax liability $ 1,447 $ 1,320 PPL Electric expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. At December 31, 2019 , PPL Electric had the following loss carryforwards and related deferred tax assets: Gross Deferred Tax Asset Expiration Loss carryforwards Federal net operating losses $ 363 $ 76 2032-2037 Federal charitable contributions 9 2 2020-2024 State net operating losses 81 6 2031-2032 Credit carryforwards were insignificant at December 31, 2019 . 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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 44 $ 2 $ (65 ) Current - State 15 9 20 Total Current Expense (Benefit) 59 11 (45 ) Deferred - Federal (a) 51 96 234 Deferred - State 39 37 29 Total Deferred Expense (Benefit), excluding operating loss carryforwards 90 133 263 Tax expense (benefit) of operating loss carryforwards Deferred - Federal — (8 ) (5 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards — (8 ) (5 ) Total income tax expense (benefit) $ 149 $ 136 $ 213 Total income tax expense (benefit) - Federal $ 95 $ 90 $ 164 Total income tax expense (benefit) - State 54 46 49 Total income tax expense (benefit) $ 149 $ 136 $ 213 (a) Due to the enactment of the TCJA in 2017, PPL Electric recorded a $13 million deferred tax benefit related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities. 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 127 $ 119 $ 201 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 47 43 36 Depreciation and other items not normalized (10 ) (11 ) (8 ) Amortization of excess deferred federal income taxes (b) (18 ) (17 ) — Deferred tax impact of U.S. tax reform (c) — — (13 ) Other 3 2 (3 ) Total increase (decrease) 22 17 12 Total income tax expense (benefit) $ 149 $ 136 $ 213 Effective income tax rate 24.6 % 24.0 % 37.0 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 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. (c) In 2017, PPL Electric recorded a deferred tax benefit related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. 2019 2018 2017 Taxes, other than income State gross receipts $ 107 $ 103 $ 102 Property and other 5 6 5 Total $ 112 $ 109 $ 107 (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: 2019 2018 Deferred Tax Assets Federal loss carryforwards $ 140 $ 142 State loss carryforwards 31 33 Federal tax credit carryforwards 162 169 Contributions in aid of construction 23 21 Regulatory liabilities 44 52 Accrued pension and postretirement costs 71 92 State tax credit carryforwards 19 1 Income taxes due to customers 292 299 Deferred investment tax credits 31 32 Lease liabilities 14 — Valuation allowances (6 ) (8 ) Other 28 28 Total deferred tax assets 849 861 Deferred Tax Liabilities Plant - net 1,778 1,671 Regulatory assets 122 138 Lease right-of-use assets 12 — Other 6 8 Total deferred tax liabilities 1,918 1,817 Net deferred tax liability $ 1,069 $ 956 At December 31, 2019 , 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 $ 668 $ 140 $ — 2032 - 2037 Federal charitable contributions 23 5 — 2020 - 2024 State net operating losses 797 31 — 2029 - 2038 Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal investment tax credit 133 — 2025 - 2028, 2036 - 2039 Federal alternative minimum tax credit (a) 7 — Indefinite Federal - other 22 (6 ) 2020-2039 State - recycling credit 18 — 2028 State - other 1 — Indefinite (a) The TCJA repealed the corporate alternative minimum tax (AMT) for tax years beginning after December 31, 2017. The existing indefinite carryforward period for AMT credits was retained. Changes in deferred tax valuation allowances were: Balance at Beginning of Period Additions Deductions Balance at End of Period 2019 $ 8 $ 3 $ 5 (a) $ 6 2018 8 — — 8 2017 11 4 7 (a) 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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 20 $ 31 $ 74 Current - State — 4 6 Total Current Expense (Benefit) 20 35 80 Deferred - Federal (a) 81 65 268 Deferred - State (b) 5 34 32 Total Deferred Expense (Benefit), excluding benefits of operating loss carryforwards 86 99 300 Amortization of investment tax credit - Federal (3 ) (3 ) (3 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal — (2 ) (2 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards — (2 ) (2 ) Total income tax expense (benefit) (c) $ 103 $ 129 $ 375 Total income tax expense (benefit) - Federal $ 98 $ 91 $ 337 Total income tax expense (benefit) - State 5 38 38 Total income tax expense (benefit) (c) $ 103 $ 129 $ 375 (a) Due to the enactment of the TCJA in 2017, LKE recorded $112 million of deferred income tax expense, of which $108 million related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities and $4 million related to valuation allowances on tax credits expiring in 2021. (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 (c) Excludes deferred federal and state tax expense (benefit) recorded to OCI of $(1) million in 2019 , $5 million in 2018 and $(10) million in 2017 . 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 120 $ 121 $ 242 Increase (decrease) due to: State income taxes, net of federal income tax benefit 23 22 26 Amortization of investment tax credit (3 ) (3 ) (3 ) Amortization of excess deferred federal and state income taxes (b) (23 ) (20 ) (2 ) Deferred tax impact of U.S. tax reform (c) — — 112 Deferred tax impact of state tax reform (d) — 9 — Kentucky Recycling Credit, net of federal income tax expense (e) (18 ) — — Other 4 — — Total increase (decrease) (17 ) 8 133 Total income tax expense (benefit) $ 103 $ 129 $ 375 Effective income tax rate 18.0 % 22.5 % 54.3 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 2019 and 2018, LKE recorded lower income tax expense for the amortization of excess deferred income 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. (c) In 2017, LKE recorded deferred income tax expense primarily due to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. (d) 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. (e) 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. 2019 2018 2017 Taxes, other than income Property and other $ 74 $ 70 $ 65 Total $ 74 $ 70 $ 65 (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: 2019 2018 Deferred Tax Assets Contributions in aid of construction $ 15 $ 14 Regulatory liabilities 19 24 Accrued pension and postretirement costs 6 16 Deferred investment tax credits 8 9 Income taxes due to customers 136 139 State tax credit carryforwards 14 — Lease liabilities 5 — Valuation allowances (14 ) — Other 10 15 Total deferred tax assets 199 217 2019 2018 Deferred Tax Liabilities Plant - net 811 751 Regulatory assets 77 88 Lease right-of-use assets 4 — Other 4 6 Total deferred tax liabilities 896 845 Net deferred tax liability $ 697 $ 628 At December 31, 2019 LG&E had $14 million of state credit carryforwards that expire in 2028 . In 2019, LG&E recorded a $14 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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 4 $ — $ — Current - State 4 4 5 Total Current Expense (Benefit) 8 4 5 Deferred - Federal 46 51 112 Deferred - State 10 10 14 Total Deferred Expense (Benefit), excluding benefits of operating loss carryforwards 56 61 126 Amortization of investment tax credit - Federal (1 ) (1 ) (1 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal — — 1 Total Tax Expense (Benefit) of Operating Loss Carryforwards — — 1 Total income tax expense (benefit) $ 63 $ 64 $ 131 Total income tax expense (benefit) - Federal $ 49 $ 50 $ 112 Total income tax expense (benefit) - State 14 14 19 Total income tax expense (benefit) $ 63 $ 64 $ 131 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 62 $ 62 $ 120 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 11 14 Amortization of excess deferred federal and state income taxes (b) (10 ) (8 ) (1 ) Kentucky recycling credit, net of federal income tax expense (c) (14 ) — — Valuation allowance adjustments (c) 14 — — Other (1 ) (1 ) (2 ) Total increase (decrease) 1 2 11 Total income tax expense (benefit) $ 63 $ 64 $ 131 Effective income tax rate 21.4 % 21.5 % 38.1 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 2019 and 2018, LG&E recorded lower income tax expense for the amortization of excess deferred income 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. (c) In 2019, LG&E recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky. This amount has been reserved due to insufficient Kentucky taxable income projected at LG&E. 2019 2018 2017 Taxes, other than income Property and other $ 39 $ 36 $ 33 Total $ 39 $ 36 $ 33 (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: 2019 2018 Deferred Tax Assets Contributions in aid of construction $ 8 $ 7 Regulatory liabilities 25 28 Accrued pension and postretirement costs — 7 Deferred investment tax credits 23 23 Income taxes due to customers 156 160 State tax credit carryforwards 5 — Lease liabilities 8 — Valuation allowances (4 ) — Other 3 3 Total deferred tax assets 224 228 Deferred Tax Liabilities Plant - net 959 911 Regulatory assets 45 50 Accrued pension and postretirement costs 2 — Lease right-of-use assets 7 — Other 3 2 Total deferred tax liabilities 1,016 963 Net deferred tax liability $ 792 $ 735 At December 31, 2019 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. In 2019, KU recorded 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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 35 $ 22 $ — Current - State 5 6 7 Total Current Expense (Benefit) 40 28 7 Deferred - Federal 28 40 138 Deferred - State 13 10 16 Total Deferred Expense (Benefit) 41 50 154 Amortization of investment tax credit - Federal (2 ) (2 ) (2 ) Total income tax expense (benefit) $ 79 $ 76 $ 159 Total income tax expense (benefit) - Federal $ 61 $ 60 $ 136 Total income tax expense (benefit) - State 18 16 23 Total income tax expense (benefit) $ 79 $ 76 $ 159 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 78 $ 76 $ 146 Increase (decrease) due to: State income taxes, net of federal income tax benefit 15 13 15 Amortization of investment tax credit (2 ) (2 ) (2 ) Amortization of excess deferred federal and state income taxes (b) (13 ) (12 ) (1 ) Kentucky recycling credit, net of federal income tax expense (c) (4 ) — — Valuation allowance adjustments (c) 4 — — Other 1 1 1 Total increase (decrease) 1 — 13 Total income tax expense (benefit) $ 79 $ 76 $ 159 Effective income tax rate 21.2 % 21.0 % 38.0 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018 . (b) In 2019 and 2018, KU recorded lower income tax expense for the amortization of excess deferred income 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. (c) In 2019, KU 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 KU. 2019 2018 2017 Taxes, other than income Property and other $ 35 $ 34 $ 32 Total $ 35 $ 34 $ 32 Unrecognized Tax Benefits (All Registrants) 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, 2019 , 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) 2015 and prior 2015 and prior 2015 and prior 2015 and prior 2015 and prior Pennsylvania (state) (a) 2015 and prior 2015 and prior Kentucky (state) 2014 and prior 2014 and prior 2014 and prior 2014 and prior U.K. (foreign) 2015 and prior (a) Tax year 2013 is still subject to examination. Tax Cuts and Jobs Act (TCJA) On December 22, 2017, President Trump signed into law the TCJA. 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.

Utility Rate Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2019
Utility Rate Regulation [Line Items]
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 2019 2018 2019 2018 Current Regulatory Assets: Gas supply clause $ 8 $ 12 $ — $ — Smart meter rider 13 11 13 11 Plant outage costs 32 10 — — Transmission formula rate — — 3 — Transmission service charge 10 — 10 — Other 4 3 — — Total current regulatory assets (a) $ 67 $ 36 $ 26 $ 11 Noncurrent Regulatory Assets: Defined benefit plans $ 800 $ 963 $ 467 $ 558 Storm costs 39 56 15 22 Unamortized loss on debt 41 45 18 22 Interest rate swaps 22 20 — — Terminated interest rate swaps 81 87 — — Accumulated cost of removal of utility plant 220 200 220 200 AROs 279 273 — — Act 129 compliance rider 6 19 6 19 Other 4 10 — 3 Total noncurrent regulatory assets $ 1,492 $ 1,673 $ 726 $ 824 PPL PPL Electric 2019 2018 2019 2018 Current Regulatory Liabilities: Generation supply charge $ 23 $ 33 $ 23 $ 33 Transmission service charge — — — 3 Environmental cost recovery 5 16 — — Universal service rider 9 27 9 27 Transmission formula rate — — — 3 Fuel adjustment clause 8 — — — TCJA customer refund 61 20 59 3 Storm damage expense rider 5 5 5 5 Generation formula rate 1 7 — — Other 3 14 — — Total current regulatory liabilities $ 115 $ 122 $ 96 $ 74 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 640 $ 674 $ — $ — Power purchase agreement - OVEC 51 59 — — Net deferred taxes 1,756 1,826 588 629 Defined benefit plans 51 37 11 5 Terminated interest rate swaps 68 72 — — TCJA customer refund — 41 — 41 Other 6 5 — — Total noncurrent regulatory liabilities $ 2,572 $ 2,714 $ 599 $ 675 LKE LG&E KU 2019 2018 2019 2018 2019 2018 Current Regulatory Assets: Plant outage costs $ 32 $ 10 $ 16 $ 7 $ 16 $ 3 Gas supply clause 8 12 8 12 — — Other 1 3 1 2 — 1 Total current regulatory assets $ 41 $ 25 $ 25 $ 21 $ 16 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 333 $ 405 $ 206 $ 249 $ 127 $ 156 Storm costs 24 34 14 20 10 14 Unamortized loss on debt 23 23 14 15 9 8 Interest rate swaps 22 20 22 20 — — Terminated interest rate swaps 81 87 47 51 34 36 AROs 279 273 76 75 203 198 Other 4 7 1 1 3 6 Total noncurrent regulatory assets $ 766 $ 849 $ 380 $ 431 $ 386 $ 418 LKE LG&E KU 2019 2018 2019 2018 2019 2018 Current Regulatory Liabilities: Environmental cost recovery $ 5 $ 16 $ 1 $ 6 $ 4 $ 10 Fuel adjustment clauses 8 — — — 8 — TCJA customer refund 2 17 — 7 2 10 Generation formula rate 1 7 — — 1 7 Other 3 8 1 4 2 4 Total current regulatory liabilities $ 19 $ 48 $ 2 $ 17 $ 17 $ 31 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 640 $ 674 $ 266 $ 279 $ 374 $ 395 Power purchase agreement - OVEC 51 59 35 41 16 18 Net deferred taxes 1,168 1,197 544 557 624 640 Defined benefit plans 40 32 — — 40 32 Terminated interest rate swaps 68 72 34 36 34 36 Other 6 5 4 2 2 3 Total noncurrent regulatory liabilities $ 1,973 $ 2,039 $ 883 $ 915 $ 1,090 $ 1,124 (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, 2019 , the balances were $51 million for PPL and LKE, $29 million for LG&E and $22 million for KU. As of December 31, 2018 , the balances were $45 million for PPL and LKE, $25 million for LG&E and $20 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 various dates ending in 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-year period. TCJA Customer Refund As a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, the regulators of PPL Electric, LG&E and KU have ruled that these tax benefits should be refunded to customers. In some instances, timing differences occur between the recognition of these tax benefits and the refund of the benefit to the customers which create a regulatory asset or liability. LG&E and KU distributed these tax savings for Kentucky customers through the TCJA bill credit prior to incorporating them into base rates effective May 1, 2019. See "Regulatory Matters" for additional information. The remaining liability represents TCJA savings to be distributed to Virginia customers in 2020. PPL Electric's current liability relates to two time periods. The liability of $16 million related to the period of July 1, 2018 through December 31, 2019 will be credited back to distribution customers through a negative surcharge. The liability of $43 million related to the period of January 1, 2018 through June 30, 2018 will be 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. 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. See Note 6 for additional information on the TCJA. (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 quarters 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-year period, June 1, 2016 through May 31, 2021. The plan includes programs intended to reduce electricity consumption. The recoverable costs include direct and indirect charges, including design and development costs, general and administrative costs and applicable state evaluator costs. The rates are applied to customers who receive distribution service through the Act 129 Compliance Rider. The actual Phase III program costs are reconcilable after each 12 month period, and any over- or under-recovery from customers will be refunded or recovered over the next rate filing period. 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. (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 a return on equity of 9.725% for all existing approved ECR plans and 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 public hearings 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, 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 . LG&E's fuel adjustment clause asset is included within other current regulatory assets above. KU also employs a levelized fuel factor mechanism for Virginia customers using an average fuel cost factor based primarily on projected fuel costs. The Virginia levelized fuel factor allows fuel recovery based on projected fuel costs for the coming year plus an adjustment for any under- or over-recovery of fuel expenses from the prior 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 13 and 18 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. (PPL, LKE and LG&E) Gas Supply Clause 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). 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 . (PPL, LKE and KU) Generation Formula Rate 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. Regulatory Matters (PPL, LKE, LG&E and KU) Kentucky Activities Rate Case Proceedings In September 2018, LG&E and KU filed requests with the KPSC for an increase in annual base electricity rates of approximately $112 million at KU and increases in annual base electricity and gas rates of approximately $35 million and $25 million at LG&E. LG&E's and KU's applications also sought to include changes associated with the TCJA and state tax reform in the calculation of the proposed base rates and to terminate the TCJA bill credit mechanism when new base rates would go into effect. The elimination of the TCJA bill credit mechanism will result in an estimated annual electricity revenue increase of approximately $58 million at KU and increases in electricity and gas revenues of approximately $40 million and $12 million at LG&E. The applications were based on a forecasted test year of May 1, 2019 through April 30, 2020 with a requested return-on-equity of 10.42% . In March 2019, LG&E and KU, along with substantially all intervening parties to the proceeding, filed stipulation and recommendation agreements (stipulations) with the KPSC resolving all material issues with the parties. In addition to terminating the TCJA bill credit mechanism, the proposed stipulations provided for increases in annual revenue requirements associated with base electricity rates of approximately $58 million at KU and increases in annual base electricity and gas rates of approximately $4 million and $20 million at LG&E, based on a 9.725% return-on-equity. On April 30, 2019, the KPSC issued orders ruling on open issues and approving the proposed stipulations filed in March 2019. The orders provide for increases in the revenue requirements associated with base electricity rates of $56 million at KU and increases associated with base electricity and gas rates of $2 million and $19 million at LG&E. With the termination of the TCJA bill credit mechanism, this represents annual revenue increases of $187 million ( $114 million at KU and $73 million at LG&E). The new base rates and all elements of the orders became effective on May 1, 2019. (PPL and PPL Electric) Pennsylvania Activities Distribution of TCJA Savings In November 2019, the PUC approved PPL Electric's October 2019 petition to distribute the $43 million of TCJA tax savings for the period between January 1, 2018 and June 30, 2018 over the period January 1, 2020 through December 31, 2020. Federal Matters FERC Transmission Formula Rate In April 2019, PPL Electric filed its annual transmission formula rate update with the FERC, reflecting a revised revenue requirement, which includes the impact of the TCJA. The filing established the revenue requirement used to set rates that took effect in June 2019. (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 seeks 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 on-going 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. These rehearing requests are currently pending before FERC. Additionally, certain petitions for review of FERC's orders have been filed by multiple parties, including LG&E and KU, at the D.C. Circuit Court of Appeals. LG&E and KU cannot predict the outcome of the proceedings. LG&E and KU currently receive recovery of 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. LG&E and KU are currently reviewing the Final Rule and will submit a compliance filing addressing excess ADIT by June 1, 2020. 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 2019 , 2018 and 2017 , PPL Electric purchased $1.2 billion , $1.3 billion and $1.3 billion of accounts receivable from alternative suppliers.

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2019
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 borrowed below are recorded as "Short-term debt" on the Balance Sheets except for borrowings under LG&E's Term Loan Facility which are recorded as "Long-term debt due within one year" on the December 31, 2018 Balance Sheet. The following credit facilities were in place at: December 31, 2019 December 31, 2018 Expiration Date Capacity Borrowed Letters of Credit and Commercial Paper Issued Unused Capacity Borrowed Letters of Credit and Commercial Paper Issued PPL U.K. WPD plc Syndicated Credit Facility (a)(b)(c) Jan. 2023 £ 210 £ 155 £ — £ 55 £ 157 £ — WPD (South West) Syndicated Credit Facility (a)(b)(c) July 2021 245 40 — 205 — — WPD (East Midlands) Syndicated Credit Facility (a)(b)(c) July 2021 300 — — 300 38 — WPD (West Midlands) Syndicated Credit Facility (a)(b)(c) July 2021 300 48 — 252 — — Uncommitted Credit Facilities 100 — 4 96 — 4 Total U.K. Credit Facilities (b) £ 1,155 £ 243 £ 4 £ 908 £ 195 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Jan 2024 $ 1,450 $ 450 $ 1,000 $ — $ 669 Bilateral Credit Facility (c) (d) Mar 2020 100 — 15 85 — 15 Total PPL Capital Funding Credit Facilities $ 1,550 $ — $ 465 $ 1,085 $ — $ 684 PPL Electric Syndicated Credit Facility (c) (d) Jan 2024 $ 650 $ — $ 1 $ 649 $ — $ 1 December 31, 2019 December 31, 2018 Expiration Date Capacity Borrowed Letters of Credit and Commercial Paper Issued Unused Capacity Borrowed Letters of Credit and Commercial Paper Issued LG&E Syndicated Credit Facility (c) (d) Jan 2024 $ 500 $ — $ 238 $ 262 $ — $ 279 Term Loan Credit Facility (c) (e) — — — — 200 — Total LG&E Credit Facilities $ 500 $ — $ 238 $ 262 $ 200 $ 279 KU Syndicated Credit Facility (c) (d) Jan 2024 $ 400 $ — $ 150 $ 250 $ — $ 235 Letter of Credit Facility (f) — — — — — 198 Total KU Credit Facilities $ 400 $ — $ 150 $ 250 $ — $ 433 (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, 2019 and 2018 included USD-denominated borrowings of $200 million for both periods, which bore interest at 2.52% and 3.17% . The WPD (South West) amount borrowed at December 31, 2019 was a GBP-denominated borrowing, which equated to $51 million and bore interest at 1.09% . The WPD (East Midlands) amount borrowed at December 31, 2018 was a GBP- denominated borrowing which equated to $48 million and bore interest at 1.12% . The WPD (West Midlands) amount borrowed at December 31, 2019 was a GBP-denominated borrowing, which equated to $62 million and bore interest at 1.11% . At December 31, 2019 , the unused capacity under the U.K. credit facilities was approximately $1.2 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 2020 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. (e) LG&E entered into a $200 million term loan credit agreement in October 2017. All borrowings were repaid and the facility expired in 2019. The outstanding borrowings at December 31, 2018 bore interest at an average rate of 2.97% . (f) KU's letter of credit facility was terminated in September 2019 in connection with the bond remarketings discussed below. 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, 2019 December 31, 2018 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding 2.13% $ 1,500 $ 450 $ 1,050 2.82% $ 669 PPL Electric 650 — 650 — LG&E 2.07% 350 238 112 2.94% 279 KU 2.02% 350 150 200 2.94% 235 Total $ 2,850 $ 838 $ 2,012 $ 1,183 (PPL Electric, LKE, LG&E and KU) See Note 14 for a discussion of intercompany borrowings. Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (g) 2019 2018 PPL U.S. Senior Unsecured Notes 3.88 % 2020 - 2047 $ 4,325 $ 4,325 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.95 % 2020 - 2049 8,705 7,705 Junior Subordinated Notes 5.24 % 2067 - 2073 930 930 Term Loan Credit Facility 2019 — 200 Total U.S. Long-term Debt 13,960 13,160 U.K. Senior Unsecured Notes (d) 4.97 % 2020 - 2040 6,874 6,471 Index-linked Senior Unsecured Notes (e) 1.45 % 2026 - 2056 1,104 1,063 Term Loan Credit Facility 2.18 % 2024 - 2024 64 — Total U.K. Long-term Debt (f) 8,042 7,534 Total Long-term Debt Before Adjustments 22,002 20,694 Fair market value adjustments 12 16 Unamortized premium and (discount), net 5 9 Unamortized debt issuance costs (126 ) (120 ) Total Long-term Debt 21,893 20,599 Less current portion of Long-term Debt 1,172 530 Total Long-term Debt, noncurrent $ 20,721 $ 20,069 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.08 % 2021 - 2049 $ 4,039 $ 3,739 Total Long-term Debt Before Adjustments 4,039 3,739 Unamortized discount (24 ) (18 ) Unamortized debt issuance costs (30 ) (27 ) Total Long-term Debt 3,985 3,694 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 3,985 $ 3,694 LKE Senior Unsecured Notes 3.97 % 2020 - 2021 $ 725 $ 725 Term Loan Credit Facility — 200 First Mortgage Bonds (a) (c) 3.84 % 2020 - 2049 4,666 3,966 Long-term debt to affiliate 3.69 % 2026 - 2028 650 650 Total Long-term Debt Before Adjustments 6,041 5,541 Unamortized premium 5 — Unamortized discount (12 ) (13 ) Unamortized debt issuance costs (32 ) (26 ) Total Long-term Debt 6,002 5,502 Less current portion of Long-term Debt 975 530 Total Long-term Debt, noncurrent $ 5,027 $ 4,972 December 31, Weighted-Average Maturities (g) 2019 2018 LG&E Term Loan Credit Facility $ — $ 200 First Mortgage Bonds (a) (c) 3.73 % 2025 - 2049 2,024 1,624 Total Long-term Debt Before Adjustments 2,024 1,824 Unamortized discount (4 ) (4 ) Unamortized debt issuance costs (15 ) (11 ) Total Long-term Debt 2,005 1,809 Less current portion of Long-term Debt — 434 Total Long-term Debt, noncurrent $ 2,005 $ 1,375 KU First Mortgage Bonds (a) (c) 3.93 % 2020 - 2045 $ 2,642 $ 2,342 Total Long-term Debt Before Adjustments 2,642 2,342 Unamortized premium 5 — Unamortized discount (8 ) (8 ) Unamortized debt issuance costs (16 ) (13 ) Total Long-term Debt 2,623 2,321 Less current portion of Long-term Debt 500 96 Total Long-term Debt, noncurrent $ 2,123 $ 2,225 (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 $10.1 billion and $9.4 billion at December 31, 2019 and 2018 . 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 $5.3 billion and $5.1 billion at December 31, 2019 and 2018 . 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 $6.6 billion and $6.3 billion at December 31, 2019 and 2018 . (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 that may be redeemed, in whole or in part, at par beginning in October 2020, and are 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. (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, 2019 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $700 million for LKE, comprised of $392 million and $308 million for LG&E and KU respectively. At December 31, 2019 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $181 million for LKE, comprised of $148 million and $33 million for LG&E 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 ( $291 million at December 31, 2019 ) 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 2018 to 2019 was an increase of approximately £20 million ( $26 million ) resulting from inflation. In addition, this amount includes £327 million ( $423 million at December 31, 2019 ) 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 £5.7 billion ( $7.4 billion at December 31, 2019 ) 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, 2019 . 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 2020 through 2024 and thereafter are as follows: PPL PPL Electric LKE LG&E KU 2020 $ 1,169 $ — $ 975 $ — $ 500 2021 1,574 400 674 292 132 2022 1,274 474 — — — 2023 2,254 90 13 — 13 2024 932 — — — — Thereafter 14,799 3,075 4,379 1,732 1,997 Total $ 22,002 $ 4,039 $ 6,041 $ 2,024 $ 2,642 (PPL) In June 2019, WPD plc executed and drew £50 million under a 5-year term loan facility due 2024 at a rate of 2.189% , to be reset quarterly as detailed in the terms of the facility. The borrowing equated to $63 million at the time of drawdown, net of fees. The proceeds were used for general corporate purposes. In September 2019, WPD (East Midlands) issued £250 million of 1.75% Senior Notes due 2031. WPD (East Midlands) received proceeds of £245 million , which equated to $301 million at the time of issuance, net of fees and a discount. The proceeds were used to repay short-term debt and for general corporate purposes. (PPL and PPL Electric) In September 2019, PPL Electric issued $400 million of 3.00% First Mortgage Bonds due 2049. PPL Electric received proceeds of $390 million , net of a discount and underwriting fees, which were used to repay short-term debt and for general corporate purposes. In December 2019, PPL Electric redeemed all of the outstanding $100 million aggregate principal amount of its Senior Secured Bonds, 5.15% Series due 2020. (PPL, LKE and LG&E) In April 2019, LG&E issued $400 million of 4.25% First Mortgage Bonds due 2049. LG&E received proceeds of $396 million , net of discounts and underwriting fees, which were used to repay commercial paper and LG&E's term loan. In April 2019, the County of Jefferson, Kentucky remarketed $128 million of Pollution Control Revenue Bonds, 2001 Series A due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.85% through their mandatory purchase date of April 1, 2021. In June 2019, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.65% through their mandatory purchase date of June 1, 2021. In June 2019, the Louisville/Jefferson County Metro Government of Kentucky remarketed $35 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series B due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.65% through their mandatory purchase date of June 1, 2021. In June 2019, LG&E issued a notice to bondholders of its intention to convert the $40 million Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A to a weekly interest rate, as permitted under the loan documents. The conversion was completed on August 1, 2019. In connection with the conversation, LG&E purchased these bonds from the remarketing agent and held them until September 17, 2019, at which time LG&E remarketed the bonds at a long-term rate that will bear interest at 1.75% through their mandatory purchase date of July 1, 2026. (PPL, LKE and KU) In April 2019, KU reopened its 4.375% First Mortgage Bonds due 2045 and issued an additional $300 million of this series. KU received proceeds of $303 million , including premiums and underwriting fees, which were used to repay commercial paper and for other general corporate purposes. In September 2019, the County of Carroll, Kentucky remarketed $50 million of Environmental Facilities Revenue Bonds, 2004 Series A due 2034 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.75% through their mandatory purchase date of September 1, 2026. In September 2019, the County of Carroll, Kentucky remarketed $96 million of Pollution Control Revenue Bonds, 2016 Series A due 2042 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.55% through their mandatory purchase date of September 1, 2026. In September 2019, the County of Carroll, Kentucky remarketed $54 million of Environmental Facilities Revenue Bonds, 2006 Series B due 2034 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.20% through their mandatory purchase date of June 1, 2021. In September 2019, the County of Carroll, Kentucky remarketed $78 million of Environmental Facilities Revenue Bonds, 2008 Series A due 2032 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.20% through their mandatory purchase date of June 1, 2021. In September 2019, the County of Mercer, Kentucky remarketed $13 million of Solid Waste Disposal Facility Revenue Bonds, 2000 Series A due 2023 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.30% through their maturity date of May 1, 2023. See Note 14 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 Equity Forward Contracts In May 2018, PPL completed a registered underwritten public offering of 55 million shares of its common stock. In conjunction with that offering, the underwriters exercised an option to purchase 8.25 million additional shares of PPL common stock solely to cover over-allotments. In connection with the registered public offering, PPL entered into forward sale agreements with two counterparties covering the total 63.25 million shares of PPL common stock. Under the forward sale agreements, PPL was obligated to settle these forward sale agreements no later than November 2019. The forward sale agreements were classified as equity transactions. In September 2018, PPL settled a portion of the initial forward sale agreements by issuing 20 million shares of PPL common stock, resulting in net cash proceeds of $520 million . In November 2019, PPL settled the remaining 43.25 million shares of PPL common stock, resulting in net cash proceeds of $1.1 billion . The net proceeds received will be used for general corporate purposes. See Note 5 for information on the forward sale agreements impact on the calculation of diluted EPS. 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, 2019. PPL issued 42 million shares of common stock and received proceeds of $119 million for the year ended December 31, 2018. Distributions and Related Restrictions In November 2019 , PPL declared its quarterly common stock dividend, payable January 2, 2020, at 41.25 cents per share (equivalent to $1.65 per annum). On February 14, 2020 , PPL announced an increase of its quarterly common stock dividend to 41.5 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, 2019 , 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, 2019 , 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 $3.3 billion ( $1.5 billion for LG&E and $1.8 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.

Leases

Leases	12 Months Ended
	Dec. 31, 2019
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. At December 31, 2019 , PPL, LKE, LG&E and KU expect to receive the following fixed lease payments over the remaining term of their operating lease agreements: PPL LKE LG&E KU 2020 $ 13 $ 7 $ — $ 7 2021 11 5 — 5 2022 5 — — — 2023 5 1 — — 2024 3 — — — Thereafter 12 — — — Total $ 49 $ 13 $ — $ 12 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 2020 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. For leases that existed as of December 31, 2018, payments associated with renewal options are not included in the measurement of the lease liability and right-of-use (ROU) asset. 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. Practical Expedients See Note 1 for information on the adoption of the new lease guidance as well as the practical expedients the Registrants have elected as part of the transition. (PPL, LKE, LG&E and KU) Lessee Transactions The following table provides the components of lease cost for the Registrants' operating leases for the year ended December 31, 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, 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, 2019 . PPL LKE LG&E KU 2020 $ 29 $ 18 $ 7 $ 11 2021 22 13 5 8 2022 17 9 4 5 2023 15 7 3 4 2024 12 6 2 4 Thereafter 27 8 3 4 Total $ 122 $ 61 $ 24 $ 36 Weighted-average discount rate 3.48 % 3.96 % 3.89 % 4.01 % Weighted-average remaining lease term (in years) 8 5 5 5 Current lease liabilities (a) $ 26 $ 16 $ 6 $ 10 Non-current lease liabilities (a) 78 39 15 23 Right-of-use assets (b) 96 47 18 28 (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. At December 31, 2018, the total future minimum rental payments for all operating leases were estimated to be: PPL LKE LG&E KU 2019 $ 26 $ 20 $ 10 $ 10 2020 21 15 6 9 2021 15 11 4 7 2022 13 7 3 4 2023 8 6 3 3 Thereafter 33 11 4 6 Total $ 116 $ 70 $ 30 $ 39

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2019
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, Governance and Nominating Committee (CGNC) 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 Total As % of Outstanding Annual Grant Annual Grant Limit For Individual Participants - Performance Based Awards Award Limit PPL Common Stock On First Day of Limit Options For awards denominated in For awards denominated in 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: 2019 2018 2017 PPL $ 31.95 $ 30.58 $ 35.30 PPL Electric 32.33 30.00 35.45 LKE 30.65 30.98 35.25 Restricted stock unit activity for 2019 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,098,203 $ 33.45 Granted 479,428 31.95 Vested (429,258 ) 33.64 Forfeited (10,688 ) 31.53 Nonvested, end of period 1,137,685 32.76 PPL Electric Nonvested, beginning of period 187,337 $ 33.09 Transfer between registrants (3,305 ) 33.06 Granted 112,138 32.33 Vested (59,661 ) 33.77 Forfeited (6,649 ) 31.01 Nonvested, end of period 229,860 32.61 LKE Nonvested, beginning of period 133,030 $ 33.45 Granted 76,256 30.65 Vested (42,841 ) 33.75 Nonvested, end of period 166,445 32.09 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: 2019 2018 2017 PPL $ 13 $ 16 $ 20 PPL Electric 2 2 3 LKE 1 5 4 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-year performance period. At the end of the period, payout is determined by comparing PPL's performance to the TSR of the companies included in the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each year's awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the CGNC's determination of achievement of the performance goals. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment other than retirement, one year or more from commencement of the performance period, disability or death of an employee. 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-year period, the minimum vesting period required for an employee to be entitled to payout of the awards with no proration. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three-year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year. If an employee retires before the one-year vesting period, the performance units are forfeited. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans. 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: 2019 2018 2017 Expected stock volatility 17.57 % 17.60 % 17.40 % Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2019 2018 2017 PPL $ 35.83 $ 38.26 $ 38.38 PPL Electric 35.68 38.37 38.37 LKE 35.93 38.32 38.24 TSR performance unit activity for 2019 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 840,124 $ 37.89 Granted 250,734 35.83 Forfeited (a) (351,466 ) 37.24 Nonvested, end of period 739,392 37.50 PPL Electric Nonvested, beginning of period 67,863 $ 37.86 Granted 24,158 35.68 Forfeited (a) (25,222 ) 36.92 Nonvested, end of period 66,799 37.43 LKE Nonvested, beginning of period 148,996 $ 37.81 Granted 39,453 35.93 Forfeited (a) (57,916 ) 37.02 Nonvested, end of period 130,533 37.60 (a) Primarily related to the forfeiture of 2016 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 year ended December 31, 2019 and the total fair value of TSR performance units vesting for the year ended December 31, 2018 and 2017 was $3 million and $8 million for PPL and insignificant for PPL Electric and LKE. 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-year performance period for PPL Corporation. ROE 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 ROE performance goal. ROE performance units can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the CGNC's determination of achievement of the performance goals. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment other than retirement, disability or death of an employee. 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: 2019 2018 2017 PPL $ 30.89 $ 32.21 $ 32.42 PPL Electric 30.76 32.32 34.41 LKE 30.99 32.28 34.29 ROE performance unit activity for 2019 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 328,958 $ 32.86 Granted 241,807 30.89 Nonvested, end of period 570,765 32.02 PPL Electric Nonvested, beginning of period 25,960 $ 32.96 Granted 23,234 30.76 Nonvested, end of period 49,194 31.92 LKE Nonvested, beginning of period 69,620 $ 32.87 Granted 38,185 30.99 Nonvested, end of period 107,805 32.20 Stock Options PPL's CGNC 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, 2019 , 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 2019 was: Number of Options Weighted Average Exercise Price Per Share Weighted- Average Remaining Contractual Term (years) Aggregate Total Intrinsic Value PPL Outstanding at beginning of period 2,914,525 $ 26.26 Exercised (1,578,554 ) 26.31 Forfeited (5,028 ) 28.77 Outstanding and exercisable at end of period 1,330,943 26.20 2.5 $ 13 For 2019 , 2018 and 2017 , PPL received $53 million , $5 million and $19 million in cash from stock options exercised. The total intrinsic value of stock options exercised for 2019 was $11 million , insignificant in 2018 and $8 million for 2017 . 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: 2019 2018 2017 PPL $ 35 $ 25 $ 32 PPL Electric 12 10 18 LKE 9 8 8 The income tax benefit related to above compensation expense was as follows: 2019 2018 2017 PPL $ 10 $ 10 $ 13 PPL Electric 3 3 8 LKE 2 2 3 At December 31, 2019 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 14 1.9 PPL Electric 3 2.2 LKE 1 1.5
PPL Electric Utilities Corp [Member]
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, Governance and Nominating Committee (CGNC) 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 Total As % of Outstanding Annual Grant Annual Grant Limit For Individual Participants - Performance Based Awards Award Limit PPL Common Stock On First Day of Limit Options For awards denominated in For awards denominated in 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: 2019 2018 2017 PPL $ 31.95 $ 30.58 $ 35.30 PPL Electric 32.33 30.00 35.45 LKE 30.65 30.98 35.25 Restricted stock unit activity for 2019 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,098,203 $ 33.45 Granted 479,428 31.95 Vested (429,258 ) 33.64 Forfeited (10,688 ) 31.53 Nonvested, end of period 1,137,685 32.76 PPL Electric Nonvested, beginning of period 187,337 $ 33.09 Transfer between registrants (3,305 ) 33.06 Granted 112,138 32.33 Vested (59,661 ) 33.77 Forfeited (6,649 ) 31.01 Nonvested, end of period 229,860 32.61 LKE Nonvested, beginning of period 133,030 $ 33.45 Granted 76,256 30.65 Vested (42,841 ) 33.75 Nonvested, end of period 166,445 32.09 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: 2019 2018 2017 PPL $ 13 $ 16 $ 20 PPL Electric 2 2 3 LKE 1 5 4 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-year performance period. At the end of the period, payout is determined by comparing PPL's performance to the TSR of the companies included in the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each year's awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the CGNC's determination of achievement of the performance goals. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment other than retirement, one year or more from commencement of the performance period, disability or death of an employee. 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-year period, the minimum vesting period required for an employee to be entitled to payout of the awards with no proration. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three-year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year. If an employee retires before the one-year vesting period, the performance units are forfeited. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans. 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: 2019 2018 2017 Expected stock volatility 17.57 % 17.60 % 17.40 % Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2019 2018 2017 PPL $ 35.83 $ 38.26 $ 38.38 PPL Electric 35.68 38.37 38.37 LKE 35.93 38.32 38.24 TSR performance unit activity for 2019 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 840,124 $ 37.89 Granted 250,734 35.83 Forfeited (a) (351,466 ) 37.24 Nonvested, end of period 739,392 37.50 PPL Electric Nonvested, beginning of period 67,863 $ 37.86 Granted 24,158 35.68 Forfeited (a) (25,222 ) 36.92 Nonvested, end of period 66,799 37.43 LKE Nonvested, beginning of period 148,996 $ 37.81 Granted 39,453 35.93 Forfeited (a) (57,916 ) 37.02 Nonvested, end of period 130,533 37.60 (a) Primarily related to the forfeiture of 2016 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 year ended December 31, 2019 and the total fair value of TSR performance units vesting for the year ended December 31, 2018 and 2017 was $3 million and $8 million for PPL and insignificant for PPL Electric and LKE. 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-year performance period for PPL Corporation. ROE 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 ROE performance goal. ROE performance units can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the CGNC's determination of achievement of the performance goals. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment other than retirement, disability or death of an employee. 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: 2019 2018 2017 PPL $ 30.89 $ 32.21 $ 32.42 PPL Electric 30.76 32.32 34.41 LKE 30.99 32.28 34.29 ROE performance unit activity for 2019 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 328,958 $ 32.86 Granted 241,807 30.89 Nonvested, end of period 570,765 32.02 PPL Electric Nonvested, beginning of period 25,960 $ 32.96 Granted 23,234 30.76 Nonvested, end of period 49,194 31.92 LKE Nonvested, beginning of period 69,620 $ 32.87 Granted 38,185 30.99 Nonvested, end of period 107,805 32.20 Stock Options PPL's CGNC 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, 2019 , 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 2019 was: Number of Options Weighted Average Exercise Price Per Share Weighted- Average Remaining Contractual Term (years) Aggregate Total Intrinsic Value PPL Outstanding at beginning of period 2,914,525 $ 26.26 Exercised (1,578,554 ) 26.31 Forfeited (5,028 ) 28.77 Outstanding and exercisable at end of period 1,330,943 26.20 2.5 $ 13 For 2019 , 2018 and 2017 , PPL received $53 million , $5 million and $19 million in cash from stock options exercised. The total intrinsic value of stock options exercised for 2019 was $11 million , insignificant in 2018 and $8 million for 2017 . 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: 2019 2018 2017 PPL $ 35 $ 25 $ 32 PPL Electric 12 10 18 LKE 9 8 8 The income tax benefit related to above compensation expense was as follows: 2019 2018 2017 PPL $ 10 $ 10 $ 13 PPL Electric 3 3 8 LKE 2 2 3 At December 31, 2019 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 14 1.9 PPL Electric 3 2.2 LKE 1 1.5
LG And E And KU Energy LLC [Member]
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, Governance and Nominating Committee (CGNC) 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 Total As % of Outstanding Annual Grant Annual Grant Limit For Individual Participants - Performance Based Awards Award Limit PPL Common Stock On First Day of Limit Options For awards denominated in For awards denominated in 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: 2019 2018 2017 PPL $ 31.95 $ 30.58 $ 35.30 PPL Electric 32.33 30.00 35.45 LKE 30.65 30.98 35.25 Restricted stock unit activity for 2019 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,098,203 $ 33.45 Granted 479,428 31.95 Vested (429,258 ) 33.64 Forfeited (10,688 ) 31.53 Nonvested, end of period 1,137,685 32.76 PPL Electric Nonvested, beginning of period 187,337 $ 33.09 Transfer between registrants (3,305 ) 33.06 Granted 112,138 32.33 Vested (59,661 ) 33.77 Forfeited (6,649 ) 31.01 Nonvested, end of period 229,860 32.61 LKE Nonvested, beginning of period 133,030 $ 33.45 Granted 76,256 30.65 Vested (42,841 ) 33.75 Nonvested, end of period 166,445 32.09 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: 2019 2018 2017 PPL $ 13 $ 16 $ 20 PPL Electric 2 2 3 LKE 1 5 4 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-year performance period. At the end of the period, payout is determined by comparing PPL's performance to the TSR of the companies included in the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each year's awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the CGNC's determination of achievement of the performance goals. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment other than retirement, one year or more from commencement of the performance period, disability or death of an employee. 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-year period, the minimum vesting period required for an employee to be entitled to payout of the awards with no proration. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three-year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year. If an employee retires before the one-year vesting period, the performance units are forfeited. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans. 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: 2019 2018 2017 Expected stock volatility 17.57 % 17.60 % 17.40 % Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2019 2018 2017 PPL $ 35.83 $ 38.26 $ 38.38 PPL Electric 35.68 38.37 38.37 LKE 35.93 38.32 38.24 TSR performance unit activity for 2019 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 840,124 $ 37.89 Granted 250,734 35.83 Forfeited (a) (351,466 ) 37.24 Nonvested, end of period 739,392 37.50 PPL Electric Nonvested, beginning of period 67,863 $ 37.86 Granted 24,158 35.68 Forfeited (a) (25,222 ) 36.92 Nonvested, end of period 66,799 37.43 LKE Nonvested, beginning of period 148,996 $ 37.81 Granted 39,453 35.93 Forfeited (a) (57,916 ) 37.02 Nonvested, end of period 130,533 37.60 (a) Primarily related to the forfeiture of 2016 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 year ended December 31, 2019 and the total fair value of TSR performance units vesting for the year ended December 31, 2018 and 2017 was $3 million and $8 million for PPL and insignificant for PPL Electric and LKE. 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-year performance period for PPL Corporation. ROE 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 ROE performance goal. ROE performance units can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the CGNC's determination of achievement of the performance goals. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment other than retirement, disability or death of an employee. 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: 2019 2018 2017 PPL $ 30.89 $ 32.21 $ 32.42 PPL Electric 30.76 32.32 34.41 LKE 30.99 32.28 34.29 ROE performance unit activity for 2019 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 328,958 $ 32.86 Granted 241,807 30.89 Nonvested, end of period 570,765 32.02 PPL Electric Nonvested, beginning of period 25,960 $ 32.96 Granted 23,234 30.76 Nonvested, end of period 49,194 31.92 LKE Nonvested, beginning of period 69,620 $ 32.87 Granted 38,185 30.99 Nonvested, end of period 107,805 32.20 Stock Options PPL's CGNC 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, 2019 , 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 2019 was: Number of Options Weighted Average Exercise Price Per Share Weighted- Average Remaining Contractual Term (years) Aggregate Total Intrinsic Value PPL Outstanding at beginning of period 2,914,525 $ 26.26 Exercised (1,578,554 ) 26.31 Forfeited (5,028 ) 28.77 Outstanding and exercisable at end of period 1,330,943 26.20 2.5 $ 13 For 2019 , 2018 and 2017 , PPL received $53 million , $5 million and $19 million in cash from stock options exercised. The total intrinsic value of stock options exercised for 2019 was $11 million , insignificant in 2018 and $8 million for 2017 . 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: 2019 2018 2017 PPL $ 35 $ 25 $ 32 PPL Electric 12 10 18 LKE 9 8 8 The income tax benefit related to above compensation expense was as follows: 2019 2018 2017 PPL $ 10 $ 10 $ 13 PPL Electric 3 3 8 LKE 2 2 3 At December 31, 2019 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 14 1.9 PPL Electric 3 2.2 LKE 1 1.5

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2019
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 2019 2018 2017 2019 2018 2017 2019 2018 2017 Net periodic defined benefit costs (credits): Service cost $ 50 $ 62 $ 65 $ 68 $ 82 $ 76 $ 6 $ 7 $ 7 Interest cost 164 156 168 187 185 178 22 21 23 Expected return on plan assets (245 ) (249 ) (231 ) (588 ) (587 ) (514 ) (18 ) (23 ) (22 ) Amortization of: Prior service cost (credit) 8 10 10 1 — — (1 ) (1 ) (1 ) Actuarial (gain) loss 56 84 69 92 151 144 1 — 1 Net periodic defined benefit costs (credits) prior to settlements and termination benefits 33 63 81 (240 ) (169 ) (116 ) 10 4 8 Settlements 1 — 1 — — — — — — Termination benefits — — 1 — — — — — — Net periodic defined benefit costs (credits) $ 34 $ 63 $ 83 $ (240 ) $ (169 ) $ (116 ) $ 10 $ 4 $ 8 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement (1 ) — (1 ) — — — — — — Net (gain) loss (121 ) 157 27 723 201 346 (18 ) 8 (28 ) Prior service cost (credit) 2 1 (1 ) — 13 — — — 8 Amortization of: Prior service (cost) credit (8 ) (10 ) (10 ) (1 ) — — 1 1 1 Actuarial gain (loss) (56 ) (84 ) (69 ) (92 ) (151 ) (144 ) (1 ) — (1 ) Total recognized in OCI and regulatory assets/liabilities (a) (184 ) 64 (54 ) 630 63 202 (18 ) 9 (20 ) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (a) $ (150 ) $ 127 $ 29 $ 390 $ (106 ) $ 86 $ (8 ) $ 13 $ (12 ) (a) 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 2019 2018 2017 2019 2018 2017 OCI $ (194 ) $ 90 $ (53 ) $ (13 ) $ 20 $ (25 ) Regulatory assets/liabilities 10 (26 ) (1 ) (5 ) (11 ) 5 Total recognized in OCI and regulatory assets/liabilities $ (184 ) $ 64 $ (54 ) $ (18 ) $ 9 $ (20 ) (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 2019 2018 2017 2019 2018 2017 Net periodic defined benefit costs (credits): Service cost $ 22 $ 25 $ 24 $ 4 $ 4 $ 4 Interest cost 66 63 68 8 8 9 Expected return on plan assets (101 ) (102 ) (92 ) (8 ) (9 ) (7 ) Amortization of: Prior service cost 8 9 8 1 1 1 Actuarial (gain) loss (a) 22 35 31 (1 ) — — Net periodic defined benefit costs (b) $ 17 $ 30 $ 39 $ 4 $ 4 $ 7 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (gain) loss $ (37 ) $ 40 $ 30 $ (14 ) $ 1 $ (14 ) Prior service cost 2 — 7 — — 8 Amortization of: Prior service credit (8 ) (9 ) (8 ) (1 ) (1 ) (1 ) Actuarial gain (loss) (22 ) (35 ) (32 ) 1 — — Total recognized in OCI and regulatory assets/liabilities (65 ) (4 ) (3 ) (14 ) — (7 ) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ (48 ) $ 26 $ 36 $ (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 $5 million in 2019 and $11 million in 2018 and 2017 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019, $6 million in 2018 and $5 million in 2017 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 2019 2018 2017 2019 2018 2017 OCI $ 13 $ (25 ) $ 33 $ (7 ) $ 4 $ (2 ) Regulatory assets/liabilities (78 ) 21 (36 ) (7 ) (4 ) (5 ) Total recognized in OCI and regulatory assets/liabilities $ (65 ) $ (4 ) $ (3 ) $ (14 ) $ — $ (7 ) (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 2018 2017 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 $ 1 Interest cost 11 12 13 Expected return on plan assets (21 ) (22 ) (22 ) Amortization of: Prior service cost 5 5 5 Actuarial loss (a) 9 7 9 Net periodic defined benefit costs (b) $ 5 $ 3 $ 6 Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: Net (gain) loss $ (19 ) $ 22 $ (9 ) Prior service cost — — 7 Amortization of: Prior service credit (5 ) (5 ) (5 ) Actuarial gain (9 ) (7 ) (9 ) Total recognized in regulatory assets/liabilities (33 ) 10 (16 ) Total recognized in net periodic defined benefit costs and regulatory assets $ (28 ) $ 13 $ (10 ) (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 LG&E's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $3 million in 2019 , $2 million in 2018 and $7 million in 2017 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019, $6 million in 2018 and $5 million in 2017 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 2019 2018 2017 2019 2018 2017 2019 2018 2017 PPL $ 18 $ 40 $ 59 $ (287 ) $ (226 ) $ (151 ) $ 8 $ 2 $ 5 PPL Electric (a) (4 ) 4 12 4 (1 ) — LKE (b) 12 21 28 2 3 5 LG&E (b) 3 4 8 2 2 3 KU (a) (b) (1 ) 2 4 — 1 1 (a) PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 14 for additional information on costs allocated to 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, $2 million for LG&E and $1 million for KU were recorded as regulatory assets in 2019 , $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2018 and $4 million for LG&E and $2 million for KU were recorded as regulatory assets in 2017 . 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 14 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 2018 2017 2019 2018 2017 LG&E Non-Union Only $ — $ 2 $ 5 $ 2 $ 2 $ 3 (PPL, LKE and LG&E) PPL, LKE and LG&E use the base mortality tables issued by the Society of Actuaries in October 2014 (RP-2014 base tables with collar and factor adjustments, where applicable) for all U.S. defined benefit pension and other postretirement benefit plans. In 2017, PPL, LKE and LG&E updated to the MP-2017 mortality improvement scale from 2006 on a generational basis and continued to use this improvement scale in 2019 . 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 2019 2018 2019 2018 2019 2018 PPL Discount rate 3.64 % 4.35 % 1.94 % 2.98 % 3.60 % 4.31 % Rate of compensation increase 3.79 % 3.79 % 3.25 % 3.50 % 3.76 % 3.76 % LKE Discount rate 3.62 % 4.35 % 3.59 % 4.32 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 3.60 % 4.33 % 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 2019 2018 2017 2019 2018 2017 2019 2018 2017 PPL Discount rate service cost 4.35 % 3.70 % 4.21 % 3.12 % 2.73 % 2.99 % 4.31 % 3.64 % 4.11 % Discount rate interest cost 4.35 % 3.70 % 4.21 % 2.62 % 2.31 % 2.41 % 4.31 % 3.64 % 4.11 % Rate of compensation increase 3.79 % 3.78 % 3.95 % 3.50 % 3.50 % 3.50 % 3.76 % 3.75 % 3.92 % Expected return on plan assets 7.25 % 7.25 % 7.00 % 7.21 % 7.23 % 7.22 % 6.46 % 6.40 % 6.21 % LKE Discount rate 4.35 % 3.69 % 4.19 % 4.32 % 3.65 % 4.12 % 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 % 7.00 % 7.00 % 7.15 % 6.82 % LG&E Discount rate 4.33 % 3.65 % 4.13 % Expected return on plan assets (a) 7.25 % 7.25 % 7.00 % (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: 2019 2018 2017 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.6 % 6.6 % 6.6 % – cost 6.6 % 6.6 % 7.0 % 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 2024 2023 2022 – cost 2023 2022 2022 (PPL) The funded status of PPL's plans at December 31 was as follows: Pension Benefits U.S. U.K. Other Postretirement Benefits 2019 2018 2019 2018 2019 2018 Change in Benefit Obligation Benefit Obligation, beginning of period $ 3,883 $ 4,288 $ 7,275 $ 8,219 $ 538 $ 589 Service cost 50 62 68 82 6 7 Interest cost 164 156 187 185 22 21 Participant contributions — — 12 13 14 13 Plan amendments 2 1 — 12 — — Actuarial (gain) loss 368 (352 ) 1,220 (406 ) 34 (34 ) Settlements (21 ) — — — — — Gross benefits paid (300 ) (272 ) (363 ) (381 ) (58 ) (58 ) Federal subsidy — — — — 1 — Currency conversion — — 116 (449 ) — — Benefit Obligation, end of period 4,146 3,883 8,515 7,275 557 538 Change in Plan Assets Plan assets at fair value, beginning of period 3,109 3,488 7,801 8,490 301 405 Actual return on plan assets 735 (260 ) 1,095 (30 ) 71 (20 ) Employer contributions 63 153 278 188 10 23 Participant contributions — — 12 13 10 11 Transfer out (a) — — — — — (65 ) Settlements (22 ) — — — — — Gross benefits paid (300 ) (272 ) (363 ) (381 ) (52 ) (53 ) Currency conversion — — 122 (479 ) — — Plan assets at fair value, end of period 3,585 3,109 8,945 7,801 340 301 Funded Status, end of period $ (561 ) $ (774 ) $ 430 $ 526 $ (217 ) $ (237 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 24 $ — $ 440 $ 535 $ 11 $ 2 Current liability (8 ) (13 ) (1 ) (1 ) (2 ) (3 ) Noncurrent liability (577 ) (761 ) (9 ) (8 ) (226 ) (236 ) Net amount recognized, end of period $ (561 ) $ (774 ) $ 430 $ 526 $ (217 ) $ (237 ) Pension Benefits U.S. U.K. Other Postretirement Benefits 2019 2018 2019 2018 2019 2018 Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 34 $ 40 $ 11 $ 12 $ 10 $ 10 Net actuarial (gain) loss 1,029 1,207 3,435 2,806 6 24 Total (b) $ 1,063 $ 1,247 $ 3,446 $ 2,818 $ 16 $ 34 Total accumulated benefit obligation for defined benefit pension plans $ 3,910 $ 3,668 $ 7,821 $ 6,689 (a) 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. (b) 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 2019 2018 2019 2018 AOCI $ 352 $ 370 $ 13 $ 21 Regulatory assets/liabilities 711 877 3 13 Total $ 1,063 $ 1,247 $ 16 $ 34 The actuarial (gain) loss for all pension plans in 2019 and 2018 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 2019 2018 2019 2018 Projected benefit obligation $ 3,861 $ 3,883 $ 10 $ 9 Fair value of plan assets 3,275 3,109 — — U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2019 2018 2019 2018 Accumulated benefit obligation $ 3,624 $ 3,668 $ 10 $ 9 Fair value of plan assets 3,275 3,109 — — (LKE) The funded status of LKE's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2019 2018 2019 2018 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,580 $ 1,771 $ 205 $ 223 Service cost 22 25 4 4 Interest cost 66 63 8 8 Participant contributions — — 7 8 Plan amendments 2 — — — Actuarial (gain) loss (b) 166 (168 ) 5 (16 ) Settlements (16 ) — — — Gross benefits paid (a) (136 ) (111 ) (21 ) (22 ) Benefit Obligation, end of period 1,684 1,580 208 205 Change in Plan Assets Plan assets at fair value, beginning of period 1,294 1,402 117 116 Actual return on plan assets 304 (106 ) 27 (9 ) Employer contributions 24 109 11 24 Participant contributions — — 7 8 Settlements (16 ) — — — Gross benefits paid (136 ) (111 ) (21 ) (22 ) Plan assets at fair value, end of period 1,470 1,294 141 117 Funded Status, end of period $ (214 ) $ (286 ) $ (67 ) $ (88 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 24 $ — $ 11 $ 2 Current liability (5 ) (4 ) (2 ) (3 ) Noncurrent liability (233 ) (282 ) (76 ) (87 ) Net amount recognized, end of period $ (214 ) $ (286 ) $ (67 ) $ (88 ) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost $ 30 $ 35 $ 10 $ 12 Net actuarial (gain) loss 380 439 (37 ) (25 ) Total $ 410 $ 474 $ (27 ) $ (13 ) Total accumulated benefit obligation for defined benefit pension plans $ 1,561 $ 1,467 (a) Gross benefits paid by the plans include lump-sum cash payments made to participants during 2019 and 2018 of $74 million and $52 million . (b) The actuarial (gain) loss for all pension plans in 2019 and 2018 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 2019 2018 2019 2018 AOCI $ 132 $ 118 $ 4 $ 10 Regulatory assets/liabilities 278 356 (31 ) (23 ) Total $ 410 $ 474 $ (27 ) $ (13 ) 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 2019 2018 Projected benefit obligation $ 1,398 $ 1,580 Fair value of plan assets 1,160 1,294 ABO in excess of plan assets 2019 2018 Accumulated benefit obligation $ 1,276 $ 1,467 Fair value of plan assets 1,160 1,294 (LG&E) The funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2019 2018 Change in Benefit Obligation Benefit Obligation, beginning of period $ 285 $ 326 Service cost 1 1 Interest cost 11 12 Actuarial (gain) loss 25 (24 ) Gross benefits paid (a) (36 ) (30 ) Benefit Obligation, end of period 286 285 Change in Plan Assets Plan assets at fair value, beginning of period 281 325 Actual return on plan assets 64 (24 ) Employer contributions 1 10 Gross benefits paid (36 ) (30 ) Plan assets at fair value, end of period 310 281 Funded Status, end of period $ 24 $ (4 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset (liability) $ 24 $ (4 ) Net amount recognized, end of period $ 24 $ (4 ) Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost $ 17 $ 22 Net actuarial loss 79 107 Total $ 96 $ 129 Total accumulated benefit obligation for defined benefit pension plan $ 286 $ 285 (a) Gross benefits paid by the plan include lump-sum cash payments made to participants during 2019 and 2018 of $21 million and $16 million . LG&E's pension plan had plan assets in excess of projected and accumulated benefit obligations at December 31, 2019 . LG&E's pension plan had projected and accumulated benefit obligations in excess of plan assets at December 31, 2018 . In addition to the plan it sponsors, 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 14 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: 2019 2018 Pension $ (7 ) $ 7 Other postretirement benefits 63 65 (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 liabilities at December 31 as follows: 2019 2018 Pension $ 179 $ 285 Other postretirement benefits 122 120 (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 14 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. 2019 2018 Pension $ (31 ) $ 1 Other postretirement benefits 16 25 Plan Assets - U.S. Pension Plans (PPL, LKE and LG&E) PPL's primary legacy pension plan and the pension plans sponsored by LKE and LG&E 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 2019 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 2019 2019 (a) 2018 (a) Target Asset Allocation (a) Growth Portfolio 57 % 55 % 55 % Equity securities 34 % 30 % Debt securities (b) 14 % 15 % Alternative investments 9 % 10 % Immunizing Portfolio 42 % 43 % 43 % Debt securities (b) 35 % 39 % Derivatives 7 % 4 % Liquidity Portfolio 1 % 2 % 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, including LG&E's plan, whose assets are invested solely in the Master Trust, which is fully disclosed below. The fair value of these plans' assets of $1.5 billion and $1.3 billion at December 31, 2019 and 2018 represents an interest of approximately 41% and 42% in the Master Trust. (LG&E) LG&E has a pension plan whose assets are invested solely in the Master Trust, which is fully disclosed below. The fair value of this plan's assets of $310 million and $281 million at December 31, 2019 and 2018 represents an interest of approximately 9% in the Master Trust. (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, 2019 December 31, 2018 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 $ 182 $ 182 $ — $ — $ 220 $ 220 $ — $ — Equity securities: U.S. Equity 194 194 — — 159 159 — — U.S. Equity fund measured at NAV (a) 451 — — — 340 — — — International equity fund at NAV (a) 554 — — — 466 — — — Commingled debt measured at NAV (a) 621 — — — 543 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 310 309 1 — 212 212 — — Corporate 951 — 931 20 899 — 874 25 Other 14 — 14 — 17 — 17 — Alternative investments: Real estate measured at NAV (a) 88 — — — 90 — — — Private equity measured at NAV (a) 62 — — — 65 — — — Hedge funds measured at NAV (a) 194 — — — 175 — — — December 31, 2019 December 31, 2018 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 3 — 3 — 33 — 33 — Insurance contracts 4 — — 4 21 — — 21 PPL Services Corporation Master Trust assets, at fair value 3,628 $ 685 $ 949 $ 24 3,240 $ 591 $ 924 $ 46 Receivables and payables, net (b) 99 (2 ) 401(h) accounts restricted for other postretirement benefit obligations (142 ) (129 ) Total PPL Services Corporation Master Trust pension assets $ 3,585 $ 3,109 (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, 2019 is as follows: Corporate debt Insurance contracts 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2018 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 24 $ 37 Actual return on plan assets Relating to assets still held at the reporting date (2 ) 1 (1 ) Relating to assets sold during the period 3 — 3 Purchases, sales and settlements 11 (4 ) 7 Balance at end of period $ 25 $ 21 $ 46 The fair value measurements of cash and cash equivalents are based on the amounts on deposit. The market approach is used to measure fair value of equity securities. The fair value measurements of equity securities (excluding commingled funds), which are generally classified as Level 1, are based on quoted prices in active markets. These securities represent actively and passively managed investments that are managed against various equity indices. Investments in commingled equity and debt funds are categorized as equity securities. Investments in commingled equity funds include funds that invest in U.S. and international equity securities. Investments in commingled debt funds include funds that invest in a diversified portfolio of emerging market debt obligations, as well as funds that invest in investment grade long-duration fixed-income securities. The fair value measurements of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. The fair value of debt securities is generally measured using a market approach, including the use of pricing models, which incorporate observable inputs. Common inputs include benchmark yields, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as payment data, future predicted cash flows, collateral performance and new issue data. For the Master Trust, these securities represent investments in securities issued by U.S. Treasury and U.S. government sponsored agencies; investments securitized by residential mortgages, auto loans, credit cards and other pooled loans; investments in investment grade and non-investment grade bonds issued by U.S. companies across several industries; investments in debt securities issued by foreign governments and corporations. Investments in real estate represent an investment in a partnership whose purpose is to manage investments in core U.S. real estate properties diversified geographically and across major property types (e.g., office, industrial, retail, etc.). The strategy is focused on properties with high occupancy rates with quality tenants. This results in a focus on high income and stable cash flows with appreciation being a secondary factor. Core real estate generally has a lower degree of leverage when compared with more speculative real estate investing strategies. The partnership has limitations on the amounts that may be redeemed based on available cash to fund redemptions. Additionally, the general partner may decline to accept redemptions when necessary to avoid adverse consequences for the partnership, including legal and tax implications, among others. The fair value of the investment is based upon a partnership unit value. Investments in private equity repres

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2019
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LKE, LG&E and KU) At December 31, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 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, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 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, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 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, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 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, 2019
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 Date Natural Gas Fuel 2022 Natural Gas Retail Supply 2021 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 2020 $ 21 $ 10 $ 31 2021 21 10 31 2022 21 10 31 2023 21 10 31 2024 22 9 31 Thereafter 276 123 399 Total $ 382 $ 172 $ 554 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2019 2018 2017 LG&E $ 15 $ 14 $ 14 KU 7 6 6 Total $ 22 $ 20 $ 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, LLC v. PPL Corporation et al. On October 29, 2018, Talen Montana filed a complaint against PPL and certain of its affiliates and current and former officers and directors in the First Judicial District of the State of Montana, Lewis & Clark County (Talen Direct Action). Talen Montana alleges that in November 2014, PPL and certain officers and directors improperly distributed to PPL's subsidiaries $733 million of the proceeds from the sale of Talen Montana's (then PPL Montana's) hydroelectric generating facilities, rendering PPL Montana insolvent. The complaint includes claims for, among other things, breach of fiduciary duty; aiding and abetting breach of fiduciary duty; breach of an LLC agreement; breach of the implied duty of good faith and fair dealing; tortious interference; negligent misrepresentation; and constructive fraud. Talen Montana is seeking unspecified damages, including punitive damages, and other relief. In December 2018, PPL moved to dismiss the Talen Direct Action for lack of jurisdiction and, in the alternative, to dismiss because Delaware is the appropriate forum to decide this case. In January 2019, Talen Montana dismissed without prejudice all current and former PPL Corporation directors from the case. The parties engaged in limited jurisdictional discovery, and the Court heard oral argument regarding the PPL parties' motion to dismiss on August 22, 2019. On December 4, 2019, the Court granted PPL's motion to dismiss and on December 26, 2019, a judgment dismissing all claims against all defendants with prejudice was signed by the Court. Talen Montana Retirement Plan and Talen Energy Marketing, LLC, Individually and on Behalf of All Others Similarly Situated v. PPL Corporation et al. Also 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. 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). The plaintiffs assert 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. They are 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 plaintiffs 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 plaintiffs' motion to remand the case back to state court, and the PPL defendants promptly petitioned the Ninth Circuit Court of Appeals to grant an appeal of the remand decision. On November 21, 2019, the Ninth Circuit Court of Appeals denied that request and on December 30, 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, LLC as a plaintiff. On January 31, 2020, PPL defendants filed a motion to dismiss the Second Amended Complaint. 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 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 point; 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, including to add claims related to indemnification with respect to the Talen Direct Action and the Talen Putative Class Action (together, 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. On October 23, 2019, the Delaware Court of Chancery returned its opinion on the defendants’ motions to dismiss sustaining all of the PPL plaintiffs' claims except for the claim for breach of implied covenant of good faith and fair dealing. Discovery is underway, however, on January 30, 2020, the defendants filed new motions to dismiss five of the remaining eight claims in the amended complaint; the PPL plaintiffs are preparing their response. A tentative trial date has been scheduled for June 2021. 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. 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. A trial has been scheduled to begin on October 5, 2020. 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 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. Discussions between the EPA and LG&E are ongoing. The parties have entered into a tolling agreement with respect to this matter through July 31, 2020. The parties are conducting initial negotiations regarding potential settlement of the matter. 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. 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 proposed rule to postpone the compliance date for certain requirements. The EPA expects to complete its reconsideration of best available technology standards by the fall of 2020. Upon completion of the ongoing regulatory proceedings, the rule will be implemented by the states in the course of their normal permitting activities. LG&E and KU are developing compliance strategies and schedules. PPL, LKE, LG&E and KU are unable to predict the outcome of the EPA's pending reconsideration of the rule or fully estimate compliance costs or timing. Additionally, 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. Costs to comply with ELGs or other discharge limits are expected to be significant. Certain costs are included in the Registrants' capital plans and are subject to rate recovery. 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. Legal challenges to the final rule are pending before the D.C. Circuit Court of Appeals. 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 to August 31, 2020, but allow certain extensions. EPA has announced that additional amendments to the rule are planned. 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 August 2020. 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. As of December 31, 2019 and December 31, 2018 , PPL Electric had a recorded liability of $10 million and $11 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 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 (including RFC or SERC) 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 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. Such agreements include, for example, 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 securities of PPL Capital Funding. (All Registrants) The table below details guarantees provided as of December 31, 2019 . "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, 2019 and $6 million at December 31, 2018 . 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 Expiration Date PPL Indemnifications related to the WPD Midlands acquisition (a) WPD indemnifications for entities in liquidation and sales of assets $ 10 (b) 2021 WPD guarantee of pension and other obligations of unconsolidated entities 83 (c) PPL Electric Guarantee of inventory value 26 (d) 2020 LKE Indemnification of lease termination and other divestitures 200 (e) 2021 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (f) (a) Indemnifications related to certain liabilities, including a specific unresolved tax issue and those relating to properties and assets owned by the seller that were transferred to WPD Midlands in connection with the acquisition. A cross indemnity has been received from the seller on the tax issue. The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents. (b) 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. (c) 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, 2019 , 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. (d) A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm currently has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold. In December 2019, PPL Electric declared its intent to terminate the firm’s inventory procurement and fulfillment services effective March 2020. This guarantee has an estimated exposure of $ 26 million , which PPL Electric will assume subsequent to the termination date. In accordance with the agreement termination terms, PPL Electric has an obligation to purchase any remaining inventory within 90 days from termination date. (e) 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. (f) 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 $110 million at December 31, 2019 , consisting of LG&E's share of $76 million and KU's share of $34 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. In October 2019, the bankruptcy court issued an order confirming the sponsor's proposed reorganization plan. OVEC and other entities are challenging the contract rejection, the bankruptcy plan confirmation and potential FERC approval of the plan in various forums, and, in December 2019, an appellate court remanded the contract rejection issue for further proceedings. The plan's effective date remains subject to certain conditions precedent, including FERC regulatory approval, and relevant aspects of the contract rejection and the plan subject to on-going appellate, bankruptcy and regulatory proceedings. OVEC and certain of its sponsors, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs, establishing or continuing debt reserve accounts or other changes involving OVEC's existing short and long-term debt. The ultimate outcome of these matters, including the sponsor bankruptcy and related appellate or regulatory proceedings, OVEC structural or finan

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2019
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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190 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, 2019 and 2018 . 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, 2019 and 2018 , $150 million and $113 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2019 and 2018 were 3.20% and 3.85% . Interest expense on the revolving line of credit was not significant for 2019 , 2018 or 2017 . 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, 2019 and 2018 . 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 ten-year notes of $400 million and $250 million with a PPL affiliate with interest rates of 3.5% and 4% . At December 31, 2019 and 2018 , the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the $400 million note was $14 million for 2019 , 2018 and 2017 . Interest Expense on the $250 million note was $10 million for 2019 and $7 million for 2018 . (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . 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 $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 11 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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190 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, 2019 and 2018 . 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, 2019 and 2018 , $150 million and $113 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2019 and 2018 were 3.20% and 3.85% . Interest expense on the revolving line of credit was not significant for 2019 , 2018 or 2017 . 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, 2019 and 2018 . 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 ten-year notes of $400 million and $250 million with a PPL affiliate with interest rates of 3.5% and 4% . At December 31, 2019 and 2018 , the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the $400 million note was $14 million for 2019 , 2018 and 2017 . Interest Expense on the $250 million note was $10 million for 2019 and $7 million for 2018 . (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . 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 $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 11 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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190 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, 2019 and 2018 . 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, 2019 and 2018 , $150 million and $113 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2019 and 2018 were 3.20% and 3.85% . Interest expense on the revolving line of credit was not significant for 2019 , 2018 or 2017 . 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, 2019 and 2018 . 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 ten-year notes of $400 million and $250 million with a PPL affiliate with interest rates of 3.5% and 4% . At December 31, 2019 and 2018 , the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the $400 million note was $14 million for 2019 , 2018 and 2017 . Interest Expense on the $250 million note was $10 million for 2019 and $7 million for 2018 . (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . 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 $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 11 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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190 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, 2019 and 2018 . 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, 2019 and 2018 , $150 million and $113 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2019 and 2018 were 3.20% and 3.85% . Interest expense on the revolving line of credit was not significant for 2019 , 2018 or 2017 . 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, 2019 and 2018 . 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 ten-year notes of $400 million and $250 million with a PPL affiliate with interest rates of 3.5% and 4% . At December 31, 2019 and 2018 , the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the $400 million note was $14 million for 2019 , 2018 and 2017 . Interest Expense on the $250 million note was $10 million for 2019 and $7 million for 2018 . (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2019 and 2018 . 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 $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 11 for discussions regarding intercompany allocations associated with defined benefits.

Other Income (Expense) - net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2019
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: 2019 2018 2017 Other Income Economic foreign currency exchange contracts (Note 17) $ (14 ) $ 150 $ (261 ) Defined benefit plans - non-service credits (Note 11) 316 257 167 Interest income 16 6 2 AFUDC - equity component 23 21 16 Miscellaneous 7 6 17 Total Other Income 348 440 (59 ) Other Expense Charitable contributions 17 24 8 Miscellaneous 22 20 21 Total Other Expense 39 44 29 Other Income (Expense) - net $ 309 $ 396 $ (88 ) (PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2019 2018 2017 Other Income Defined benefit plans - non-service credits (Note 11) $ 4 $ 5 $ 1 Interest income 2 2 1 AFUDC - equity component 23 20 15 Total Other Income 29 27 17 Other Expense Charitable contributions 3 3 2 Miscellaneous 1 1 3 Total Other Expense 4 4 5 Other Income (Expense) - net $ 25 $ 23 $ 12
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: 2019 2018 2017 Other Income Defined benefit plans - non-service credits (Note 11) $ 4 $ 5 $ 1 Interest income 2 2 1 AFUDC - equity component 23 20 15 Total Other Income 29 27 17 Other Expense Charitable contributions 3 3 2 Miscellaneous 1 1 3 Total Other Expense 4 4 5 Other Income (Expense) - net $ 25 $ 23 $ 12

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2019
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, 2019 December 31, 2018 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 815 $ 815 $ — $ — $ 621 $ 621 $ — $ — Restricted cash and cash equivalents (a) 21 21 — — 22 22 — — Special use funds (a): Money market fund — — — — 59 59 — — Commingled debt fund measured at NAV (b) 29 — — — — — — — Commingled equity fund measured at NAV (b) 27 — — — — — — — Total special use funds 56 — — — 59 59 — — Price risk management assets (c): Foreign currency contracts 142 — 142 — 202 — 202 — Cross-currency swaps 154 — 154 — 135 — 135 — Total price risk management assets 296 — 296 — 337 — 337 — Total assets $ 1,188 $ 836 $ 296 $ — $ 1,039 $ 702 $ 337 $ — Liabilities Price risk management liabilities (c): Interest rate swaps $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — Foreign currency contracts 5 — 5 — 2 — 2 — Total price risk management liabilities $ 26 $ — $ 26 $ — $ 22 $ — $ 22 $ — PPL Electric Assets Cash and cash equivalents $ 262 $ 262 $ — $ — $ 267 $ 267 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 264 $ 264 $ — $ — $ 269 $ 269 $ — $ — LKE Assets Cash and cash equivalents $ 27 $ 27 $ — $ — $ 24 $ 24 $ — $ — Total assets $ 27 $ 27 $ — $ — $ 24 $ 24 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — Total price risk management liabilities $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — LG&E Assets Cash and cash equivalents $ 15 $ 15 $ — $ — $ 10 $ 10 $ — $ — Total assets $ 15 $ 15 $ — $ — $ 10 $ 10 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — Total price risk management liabilities $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — December 31, 2019 December 31, 2018 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 KU Assets Cash and cash equivalents $ 12 $ 12 $ — $ — $ 14 $ 14 $ — $ — Total assets $ 12 $ 12 $ — $ — $ 14 $ 14 $ — $ — (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 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. In 2019, the funds are invested primarily in commingled debt and equity funds measured at NAV. The funds are classified as investments in equity securities. Changes in the fair value of the funds are recorded to the Statement of Income. In 2018, the funds were invested in money market funds. 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, 2019 December 31, 2018 Carrying Fair Value Carrying Fair Value PPL $ 21,893 $ 25,481 $ 20,599 $ 22,939 PPL Electric 3,985 4,589 3,694 3,901 LKE 6,002 6,766 5,502 5,768 LG&E 2,005 2,278 1,809 1,874 KU 2,623 3,003 2,321 2,451 (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, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 a $14 million and $40 million obligation to return cash collateral under master netting arrangements at December 31, 2019 and 2018 . PPL had no obligation to post cash collateral under master netting arrangements at December 31, 2019 and 2018 . LKE, LG&E and KU had no obligation to return cash collateral under master netting arrangements at December 31, 2019 and 2018 . LKE, LG&E and KU had no cash collateral posted under master netting arrangements at December 31, 2019 and 2018 . 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, 2019 . At December 31, 2019 , 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 2019 and 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges and had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges in 2017. At December 31, 2019 , 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 on variable rate debt. 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, 2019 , LG&E held contracts with a notional amount of $147 million that range in maturity through 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 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, 2019 . At December 31, 2019 and 2018 , PPL had $32 million and $31 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. At December 31, 2019 , the total exposure hedged by PPL was approximately £859 million (approximately $1.3 billion based on contracted rates). These contracts have termination dates ranging from January 2020 through December 2020. 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 for PPL and PPL Electric 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, 2019 and 2018 . 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, 2019 December 31, 2018 Derivatives designated as hedging instruments Derivatives not designated as hedging instruments Derivatives designated as hedging instruments Derivatives not designated as hedging instruments Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ — $ — $ — $ 4 $ — $ — $ — $ 4 Cross-currency swaps (b) 5 — — — 6 — — — Foreign currency contracts — — 142 5 — — 103 2 Total current 5 — 142 9 6 — 103 6 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 17 — — — 16 Cross-currency swaps (b) 149 — — — 129 — — — Foreign currency contracts — — — — — — 99 — Total noncurrent 149 — — 17 129 — 99 16 Total derivatives $ 154 $ — $ 142 $ 26 $ 135 $ — $ 202 $ 22 (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 Relationships Derivative Gain (Loss) Recognized in OCI Location of Gain (Loss) Recognized in Income on Derivative Gain (Loss) Reclassified from AOCI into Income 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 2017 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (9 ) Cross-currency swaps (98 ) Other Income (Expense) - net (82 ) Total $ (98 ) $ (91 ) Net Investment Hedges: Foreign currency contracts $ 1 Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized in Income on Derivative 2019 2018 2017 Foreign currency contracts Other Income (Expense) - net $ (14 ) $ 150 $ (261 ) Interest rate swaps Interest Expense (5 ) (5 ) (6 ) Total $ (19 ) $ 145 $ (267 ) Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets 2019 2018 2017 Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 6 $ 5 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, 2019 December 31, 2018 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 4 $ — $ 4 Total current — 4 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 17 — 16 Total noncurrent — 17 — 16 Total derivatives $ — $ 21 $ — $ 20 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) 2019 2018 2017 Interest rate swaps Interest Expense $ (5 ) $ (5 ) $ (6 ) Derivative Instruments Location of Gain (Loss) 2019 2018 2017 Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 6 $ 5 (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 Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20 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, LKE and LG&E) At December 31, 2019 , 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 LKE LG&E Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 3 $ 3 $ 3 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) 3 3 3 (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, 2019
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. Regulated Kentucky Regulated Corporate and Other Total 2019 2018 2019 2018 2019 2018 2019 2018 Balance at beginning of period (a) $ 2,447 $ 2,596 $ 662 $ 662 $ 53 $ — $ 3,162 $ 3,258 Effect of foreign currency exchange rates 34 (149 ) — — — — 34 (149 ) Goodwill recognized during the period (b) — — — — — 53 — 53 Other 2 — — — — — 2 — Balance at end of period (a) $ 2,483 $ 2,447 $ 662 $ 662 $ 53 $ 53 $ 3,198 $ 3,162 (a) There were no accumulated impairment losses related to goodwill. (b) Recognized as a result of the acquisition of Safari Energy. Other Intangible Assets (PPL) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Contracts (a) $ 136 $ 84 $ 137 $ 75 Land rights and easements 440 135 418 128 Licenses and other 22 3 21 1 Total subject to amortization 598 222 576 204 Not subject to amortization due to indefinite life: Land rights and easements 361 — 339 — Other 6 — 6 — Total not subject to amortization due to indefinite life 367 — 345 — Total $ 965 $ 222 $ 921 $ 204 (a) Gross carrying amount in 2019 and 2018 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: 2019 2018 2017 Intangible assets with no regulatory offset $ 9 $ 7 $ 6 Intangible assets with regulatory offset 9 8 9 Total $ 18 $ 15 $ 15 Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 Intangible assets with no regulatory offset $ 9 $ 9 $ 9 $ 9 $ 9 Intangible assets with regulatory offset 8 8 8 8 8 Total $ 17 $ 17 $ 17 $ 17 $ 17 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 370 $ 125 $ 363 $ 121 Licenses and other 3 1 2 1 Total subject to amortization 373 126 365 122 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 390 $ 126 $ 382 $ 122 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was insignificant in 2019 , 2018 and 2017 and is expected to be insignificant in future years. (LKE) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 22 $ 4 $ 21 $ 3 OVEC power purchase agreement (a) 125 74 126 66 Total subject to amortization $ 147 $ 78 $ 147 $ 69 (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: 2019 2018 2017 Intangible assets with regulatory offset $ 9 $ 8 $ 9 Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 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, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 51 87 46 Total subject to amortization $ 93 $ 52 $ 94 $ 47 (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: 2019 2018 2017 Intangible assets with regulatory offset $ 6 $ 6 $ 6 Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 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, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 15 $ 3 $ 14 $ 2 OVEC power purchase agreement (a) 39 23 39 20 Total subject to amortization $ 54 $ 26 $ 53 $ 22 (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: 2019 2018 2017 Intangible assets with regulatory offset $ 3 $ 2 $ 3 Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 Intangible assets with regulatory offset $ 2 $ 2 $ 2 $ 2 $ 2

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2019
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 13 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. 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 2019 2018 2019 2018 2019 2018 2019 2018 ARO at beginning of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235 Accretion 19 20 17 18 6 6 11 12 Obligations incurred — 8 — 8 — — — 8 Changes in estimated timing or cost 12 (3 ) (2 ) (14 ) (2 ) (2 ) — (12 ) Effect of foreign currency exchange rates — (3 ) — — — — — — Obligations settled (96 ) (72 ) (96 ) (72 ) (34 ) (22 ) (62 ) (50 ) ARO at end of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2019
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 Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the year 538 (79 ) — — (308 ) 151 Reclassifications from AOCI — 73 1 1 130 205 Net OCI during the year 538 (6 ) 1 1 (178 ) 356 December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Defined benefit plans Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total 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 (Note 1) — (1 ) — (3 ) (47 ) (51 ) 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 ) LKE December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the year — (2 ) (23 ) (25 ) Reclassifications from AOCI 1 1 5 7 Net OCI during the year 1 (1 ) (18 ) (18 ) 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 ) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2019 , 2018 and 2017 . LKE amounts are insignificant for the years ended December 31, 2019 , 2018 and 2017 . 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 11 for additional information. PPL Details about AOCI 2019 2018 2017 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (9 ) $ (8 ) $ (9 ) Interest Expense Cross-currency swaps (9 ) 42 (82 ) Other Income (Expense) - net — 1 — Interest Expense Total Pre-tax (18 ) 35 (91 ) Income Taxes 5 (6 ) 18 Total After-tax (13 ) 29 (73 ) Equity Investees' AOCI — — (1 ) Other Income (Expense) - net Total Pre-tax — — (1 ) Income Taxes — — — Total After-tax — — (1 ) Defined benefit plans Prior service costs (3 ) (2 ) (2 ) Net actuarial loss (109 ) (178 ) (167 ) Total Pre-tax (112 ) (180 ) (169 ) Income Taxes 23 36 38 Total After-tax (89 ) (144 ) (131 ) Total reclassifications during the year $ (102 ) $ (115 ) $ (205 )
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 Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the year 538 (79 ) — — (308 ) 151 Reclassifications from AOCI — 73 1 1 130 205 Net OCI during the year 538 (6 ) 1 1 (178 ) 356 December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Defined benefit plans Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total 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 (Note 1) — (1 ) — (3 ) (47 ) (51 ) 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 ) LKE December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the year — (2 ) (23 ) (25 ) Reclassifications from AOCI 1 1 5 7 Net OCI during the year 1 (1 ) (18 ) (18 ) 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 ) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2019 , 2018 and 2017 . LKE amounts are insignificant for the years ended December 31, 2019 , 2018 and 2017 . 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 11 for additional information. PPL Details about AOCI 2019 2018 2017 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (9 ) $ (8 ) $ (9 ) Interest Expense Cross-currency swaps (9 ) 42 (82 ) Other Income (Expense) - net — 1 — Interest Expense Total Pre-tax (18 ) 35 (91 ) Income Taxes 5 (6 ) 18 Total After-tax (13 ) 29 (73 ) Equity Investees' AOCI — — (1 ) Other Income (Expense) - net Total Pre-tax — — (1 ) Income Taxes — — — Total After-tax — — (1 ) Defined benefit plans Prior service costs (3 ) (2 ) (2 ) Net actuarial loss (109 ) (178 ) (167 ) Total Pre-tax (112 ) (180 ) (169 ) Income Taxes 23 36 38 Total After-tax (89 ) (144 ) (131 ) Total reclassifications during the year $ (102 ) $ (115 ) $ (205 )

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2019
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Guidance Pending Adoption	(All Registrants) Accounting for Financial Instrument Credit Losses In June 2016, the FASB issued accounting guidance that requires the use of a current expected credit loss (CECL) model for the measurement of credit losses on financial instruments within the scope of this guidance, which includes accounts receivable. The CECL model requires an entity to measure credit losses using historical information, current information and reasonable and supportable forecasts of future events, rather than the incurred loss impairment model required under current GAAP. The Registrants adopted the guidance using a modified retrospective through a cumulative-effect adjustment to retained earnings on January 1, 2020. The adoption of this guidance did not have a significant impact on the Registrants. Accounting for Implementation Costs in a Cloud Computing Service Arrangement In August 2018, the FASB issued accounting guidance that requires a customer in a cloud computing hosting arrangement that is a service contract to capitalize implementation costs consistent with internal-use software guidance for non-service arrangements. Prior guidance had not addressed these implementation costs. The guidance requires these capitalized implementation costs to be amortized over the term of the hosting arrangement to the statement of income line item where the service arrangement costs are recorded. The guidance also prescribes the financial statement classification of the capitalized implementation costs and cash flows associated with the arrangement. Additional quantitative and qualitative disclosures are also required. The Registrants adopted this guidance prospectively effective January 1, 2020. The adoption of this guidance did not have a significant impact on the Registrants. Simplifying the Test for Goodwill Impairment (PPL, LKE, LG&E and KU) In January 2017, the FASB issued accounting guidance that simplifies the test for goodwill impairment by eliminating the second step of the quantitative test. The second step of the quantitative test requires a calculation of the implied fair value of goodwill, which is determined in the same manner as the amount of goodwill in a business combination. Under this new guidance, an entity will now compare the estimated fair value of a reporting unit with its carrying value and recognize an impairment charge for the amount the carrying amount exceeds the fair value of the reporting unit. The Registrants adopted this guidance on January 1, 2020. The adoption of this guidance did not have a significant impact on the Registrants.

SCHEDULE I - CONDENSED UNCONSOL

SCHEDULE I - CONDENSED UNCONSOLICATED FINANCIAL STATEMENTS AND NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS	12 Months Ended
	Dec. 31, 2019
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) 2019 2018 2017 Other Income (Expense) - net Equity in Earnings of Subsidiaries $ 477 $ 470 $ 397 Interest Income with Affiliate 28 25 14 Total 505 495 411 Interest Expense 30 29 30 Interest Expense with Affiliate 32 28 20 Income Before Income Taxes 443 438 361 Income Tax Expense (Benefit) (25 ) (7 ) 45 Net Income $ 468 $ 445 $ 316 Total other comprehensive income (loss) (4 ) 17 (18 ) Comprehensive Income Attributable to Member $ 464 $ 462 $ 298 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) 2019 2018 2017 Cash Flows from Operating Activities Net cash provided by (used in) operating activities $ 368 $ 346 $ 401 Cash Flows from Investing Activities Capital contributions to affiliated subsidiaries (93 ) (128 ) (30 ) Net decrease (increase) in notes receivable from affiliates (44 ) (26 ) (28 ) Net cash provided by (used in) investing activities (137 ) (154 ) (58 ) Cash Flows from Financing Activities Net increase (decrease) in notes payable with affiliates 14 110 58 Contribution from member 63 — — Distribution to member (308 ) (302 ) (402 ) Net cash provided by (used in) financing activities (231 ) (192 ) (344 ) Net Increase (Decrease) in Cash and Cash Equivalents — — (1 ) Cash and Cash Equivalents at Beginning of Period — — 1 Cash and Cash Equivalents at End of Period $ — $ — $ — Supplemental disclosures of cash flow information: Cash Dividends Received from Subsidiaries $ 411 $ 402 $ 418 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) 2019 2018 Assets Current Assets Accounts receivable from affiliates $ 3 $ — Income taxes receivable 3 — Notes receivable from affiliates 1,105 1,061 Total Current Assets 1,111 1,061 Investments Affiliated companies at equity 5,577 5,422 Other Noncurrent Assets Deferred income taxes 314 299 Total Assets $ 7,002 $ 6,782 Liabilities and Equity Current Liabilities Notes payable to affiliates $ 150 $ 177 Long-term debt due within one year 475 — Accounts payable to affiliates 489 487 Taxes — 11 Other current liabilities 6 6 Total Current Liabilities 1,120 681 Long-term Debt Long-term debt 249 723 Notes payable to affiliates 691 650 Total Long-term Debt 940 1,373 Deferred Credits and Other Noncurrent Liabilities — 5 Equity 4,942 4,723 Total Liabilities and Equity $ 7,002 $ 6,782 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 13 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 See Note 8 to LKE's consolidated financial statements for the terms of LKE's outstanding senior unsecured notes outstanding. Of the total outstanding, $475 million matures in 2020 and $250 million matures in 2021. These maturities are based on stated maturities. Also see Note 8 to LKE's consolidated financial statements for the terms of LKE's $650 million in notes payable to a PPL affiliate. These notes range in maturity through 2028.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Unaudited [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL AND DIVIDEND DATA (Unaudited) PPL Corporation and Subsidiaries (Millions of Dollars, except per share data) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2019 Operating revenues $ 2,079 $ 1,803 $ 1,933 $ 1,954 Operating income 781 640 726 693 Net income 466 441 475 364 Net income available to PPL common shareowners: (b) Basic EPS 0.65 0.61 0.66 0.49 Diluted EPS 0.64 0.60 0.65 0.48 2018 Operating revenues $ 2,126 $ 1,848 $ 1,872 $ 1,939 Operating income 851 658 686 657 Net income 452 515 445 415 Net income available to PPL common shareowners: (b) Basic EPS 0.65 0.74 0.63 0.57 Diluted EPS 0.65 0.73 0.62 0.57 (a) Quarterly results can vary depending on, among other things, weather. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations. (b) The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Unaudited [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL DATA (Unaudited) PPL Electric Utilities Corporation and Subsidiaries (Millions of Dollars) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2019 Operating revenues $ 645 $ 521 $ 590 $ 602 Operating income 198 161 193 193 Net income 121 94 118 124 2018 Operating revenues $ 639 $ 517 $ 548 $ 573 Operating income 228 133 178 155 Net income 148 75 111 96 (a) PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
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 indirect, 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. The Registrants are not the primary beneficiary in any significant VIEs. 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 12 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. (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 16 and 17 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 kWh by an average rate per customer class. 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 regulatory years later. This revenue change is called the "TRU" adjustment. • 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-year lag from the time they are earned and/or assessed. Incentive revenues and penalties are included in revenues when they are billed to customers. • 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 year lag.
Accounts Receivable	Accounts Receivable (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Allowance for Doubtful Accounts Accounts 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. Accounts receivable are written off in the period in which the receivable is deemed uncollectible.
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	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 two-step 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 two-step 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, the implied fair value of goodwill must be calculated in the same manner as goodwill in a business combination. The fair value of a reporting unit is allocated to all assets and liabilities of that unit as if the reporting unit had been acquired in a business combination. The excess of the fair value of the reporting unit over the amounts assigned to its assets and liabilities is the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, goodwill is written down to its implied fair value. PPL elected to bypass the qualitative step zero evaluation of goodwill and quantitatively tested the goodwill at its WPD reporting unit while LKE, LG&E and KU qualitatively tested the goodwill of its reporting units for impairment as of the fourth quarter of 2019. No impairment was recognized.
Asset Retirement Obligations	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 19 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 11 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 10 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric and LKE includes an allocation of PPL Services' expense.
Income Taxes	Taxes Income Taxes (All Registrants) PPL and its domestic subsidiaries file a consolidated U.S. federal income tax return. Significant management judgment is required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken in 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 the 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 an 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, 2019 , no significant changes in unrecognized tax benefits are 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 entire balance is sold or otherwise disposed of. 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 for regulatory assets and liabilities is based upon the ratemaking principles reflected in rates established by the 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 9 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 recognition and measurement provisions of accounting guidance that only require disclosure. See Note 13 for further discussion of recorded and unrecorded guarantees.
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 15 for additional information.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Guidance Adopted ( All Registrants ) Accounting for Leases Effective January 1, 2019, the Registrants adopted accounting guidance that requires lessees to recognize a right-of-use asset and lease liability for leases, unless determined to meet the definition of a short-term lease. For income statement purposes, the FASB retained a dual model for lessees, requiring leases to be classified as either operating or finance. Operating leases result in straight-line expense recognition. Currently, all Registrant leases are operating leases. Lessor accounting under the new guidance is similar to the current model, but updated to align with certain changes to the lessee model and current revenue recognition guidance. Lessors classify leases as operating, direct financing, or sales-type. In adopting this new guidance, the Registrants elected to use the following practical expedients: • The Registrants did not re-assess the lease classifications or initial direct costs of existing leases. The Registrants also did not re-assess existing contracts for leases or lease classification. • The Registrants did not evaluate land easements that were not previously accounted for as leases under the new guidance. New land easements are evaluated under the new guidance beginning January 1, 2019. See Note 9 for the required disclosures resulting from the adoption of the new guidance. (PPL, LKE, LG&E & KU) The following table shows the amounts recorded on the Balance Sheets as of January 1, 2019 as a result of the adoption of the new lease guidance using a modified retrospective transition method with transition applied as of the beginning of the period of adoption: PPL LKE LG&E KU Right-of-Use Asset (a) $ 81 $ 56 $ 23 $ 31 Lease Liability - Current (b) 23 18 9 9 Lease Liability - Noncurrent (c) 67 46 18 26 (a) Right-of-Use Assets are recorded in "Other noncurrent assets" on the Balance Sheets. (b) Current lease liabilities are recorded in "Other current liabilities" on the Balance Sheets. (c) Noncurrent lease liabilities are recorded in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Improvements to Accounting for Hedging Activities Effective January 1, 2019, the Registrants adopted accounting guidance, using a modified retrospective approach, which reduces complexity when applying hedge accounting as well as improves the transparency of an entity's risk management activities. This guidance eliminates the separate measurement and reporting of hedge ineffectiveness for cash flow and net investment hedges and provides for the ability to perform subsequent qualitative effectiveness assessments. The guidance also allows entities to apply the short-cut method to partial-term fair value hedges of interest rate risk as well as expands the ability to apply the critical terms match method to cash flow hedges of groups of forecasted transactions. See Note 17 for the additional disclosures of the income statement impacts of hedging activities required from the adoption of this guidance. Disclosures related to ineffectiveness are no longer required. Other impacts of adopting this guidance were not material.
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 16 and 17 for additional information on derivatives.
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."
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 10 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric and LKE includes an allocation of PPL Services' expense.
Income Taxes	(PPL Electric, LKE, LG&E and KU)
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.
Asset Retirement Obligations	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 19 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 10 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric and LKE includes an allocation of PPL Services' expense.
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.
Asset Retirement Obligations	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 19 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.
Asset Retirement Obligations	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 19 for additional information on AROs.
Income Taxes	(PPL Electric, LKE, LG&E and KU)

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2019
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, 2019
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. (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 16 and 17 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, 2019
Summary of Significant Accounting Policies [Line Items]
Schedule of Prospective Adoption of New Accounting Pronouncements [Table Text Block]	The following table shows the amounts recorded on the Balance Sheets as of January 1, 2019 as a result of the adoption of the new lease guidance using a modified retrospective transition method with transition applied as of the beginning of the period of adoption: PPL LKE LG&E KU Right-of-Use Asset (a) $ 81 $ 56 $ 23 $ 31 Lease Liability - Current (b) 23 18 9 9 Lease Liability - Noncurrent (c) 67 46 18 26 (a) Right-of-Use Assets are recorded in "Other noncurrent assets" on the Balance Sheets. (b) Current lease liabilities are recorded in "Other current liabilities" on the Balance Sheets. (c) Noncurrent lease liabilities are recorded in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
Schedule of Valuation and Qualifying Accounts Disclosure	The changes in the allowance for doubtful accounts were: Additions Balance at Beginning of Period Charged to Income Charged to Other Accounts Deductions (a) Balance at End of Period PPL 2019 $ 56 $ 37 $ 3 $ 38 $ 58 2018 51 41 3 39 56 2017 54 28 (1 ) 30 51 PPL Electric 2019 $ 27 $ 26 $ — $ 25 $ 28 2018 24 29 — 26 27 2017 28 18 — 22 24 LKE 2019 $ 27 $ 8 $ 3 $ 10 $ 28 2018 25 10 3 11 27 2017 24 8 (1 ) 6 25 LG&E 2019 $ 1 $ 2 $ 2 $ 4 $ 1 2018 1 4 1 5 1 2017 2 2 (1 ) 2 1 KU 2019 $ 2 $ 4 $ 1 $ 6 $ 1 2018 1 5 2 6 2 2017 2 4 (1 ) 4 1 (a) Primarily related to uncollectible accounts written off.
Weighted-average Rates of Depreciation	Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2019 2018 2017 PPL 2.84 % 2.77 % 2.65 % PPL Electric 3.05 % 3.01 % 2.86 % LKE 3.96 % 3.69 % 3.64 % LG&E 3.87 % 3.63 % 3.63 % KU 4.02 % 3.74 % 3.66 %
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: PPL LKE LG&E KU 2019 2018 2019 2018 2019 2018 2019 2018 Fuel $ 106 $ 98 $ 106 $ 98 $ 43 $ 42 $ 63 $ 56 Natural gas stored underground 35 41 35 41 35 41 — — Materials and supplies 191 164 109 109 44 44 65 65 Total $ 332 $ 303 $ 250 $ 248 $ 122 $ 127 $ 128 $ 121
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 that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL PPL Electric December 31, December 31, December 31, December 31, Cash and cash equivalents $ 815 $ 621 $ 262 $ 267 Restricted cash - current 3 3 2 2 Restricted cash - noncurrent (a) 18 19 — — Total Cash, Cash Equivalents and Restricted Cash $ 836 $ 643 $ 264 $ 269 (a) Primarily consists of funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
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: 2019 2018 PPL Electric $ 3 $ 19 LKE (8 ) (16 ) LG&E (4 ) — KU (6 ) (5 )
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 that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL PPL Electric December 31, December 31, December 31, December 31, Cash and cash equivalents $ 815 $ 621 $ 262 $ 267 Restricted cash - current 3 3 2 2 Restricted cash - noncurrent (a) 18 19 — — Total Cash, Cash Equivalents and Restricted Cash $ 836 $ 643 $ 264 $ 269 (a) Primarily consists of funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
LG And E And KU Energy LLC [Member]
Summary of Significant Accounting Policies [Line Items]
Schedule of Prospective Adoption of New Accounting Pronouncements [Table Text Block]	The following table shows the amounts recorded on the Balance Sheets as of January 1, 2019 as a result of the adoption of the new lease guidance using a modified retrospective transition method with transition applied as of the beginning of the period of adoption: PPL LKE LG&E KU Right-of-Use Asset (a) $ 81 $ 56 $ 23 $ 31 Lease Liability - Current (b) 23 18 9 9 Lease Liability - Noncurrent (c) 67 46 18 26 (a) Right-of-Use Assets are recorded in "Other noncurrent assets" on the Balance Sheets. (b) Current lease liabilities are recorded in "Other current liabilities" on the Balance Sheets. (c) Noncurrent lease liabilities are recorded in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2019 2018 PPL Electric $ 3 $ 19 LKE (8 ) (16 ) LG&E (4 ) — KU (6 ) (5 )
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: PPL LKE LG&E KU 2019 2018 2019 2018 2019 2018 2019 2018 Fuel $ 106 $ 98 $ 106 $ 98 $ 43 $ 42 $ 63 $ 56 Natural gas stored underground 35 41 35 41 35 41 — — Materials and supplies 191 164 109 109 44 44 65 65 Total $ 332 $ 303 $ 250 $ 248 $ 122 $ 127 $ 128 $ 121
Louisville Gas And Electric Co [Member]
Summary of Significant Accounting Policies [Line Items]
Schedule of Prospective Adoption of New Accounting Pronouncements [Table Text Block]	The following table shows the amounts recorded on the Balance Sheets as of January 1, 2019 as a result of the adoption of the new lease guidance using a modified retrospective transition method with transition applied as of the beginning of the period of adoption: PPL LKE LG&E KU Right-of-Use Asset (a) $ 81 $ 56 $ 23 $ 31 Lease Liability - Current (b) 23 18 9 9 Lease Liability - Noncurrent (c) 67 46 18 26 (a) Right-of-Use Assets are recorded in "Other noncurrent assets" on the Balance Sheets. (b) Current lease liabilities are recorded in "Other current liabilities" on the Balance Sheets. (c) Noncurrent lease liabilities are recorded in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2019 2018 PPL Electric $ 3 $ 19 LKE (8 ) (16 ) LG&E (4 ) — KU (6 ) (5 )
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: PPL LKE LG&E KU 2019 2018 2019 2018 2019 2018 2019 2018 Fuel $ 106 $ 98 $ 106 $ 98 $ 43 $ 42 $ 63 $ 56 Natural gas stored underground 35 41 35 41 35 41 — — Materials and supplies 191 164 109 109 44 44 65 65 Total $ 332 $ 303 $ 250 $ 248 $ 122 $ 127 $ 128 $ 121
Kentucky Utilities Co [Member]
Summary of Significant Accounting Policies [Line Items]
Schedule of Prospective Adoption of New Accounting Pronouncements [Table Text Block]	The following table shows the amounts recorded on the Balance Sheets as of January 1, 2019 as a result of the adoption of the new lease guidance using a modified retrospective transition method with transition applied as of the beginning of the period of adoption: PPL LKE LG&E KU Right-of-Use Asset (a) $ 81 $ 56 $ 23 $ 31 Lease Liability - Current (b) 23 18 9 9 Lease Liability - Noncurrent (c) 67 46 18 26 (a) Right-of-Use Assets are recorded in "Other noncurrent assets" on the Balance Sheets. (b) Current lease liabilities are recorded in "Other current liabilities" on the Balance Sheets. (c) Noncurrent lease liabilities are recorded in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2019 2018 PPL Electric $ 3 $ 19 LKE (8 ) (16 ) LG&E (4 ) — KU (6 ) (5 )
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: PPL LKE LG&E KU 2019 2018 2019 2018 2019 2018 2019 2018 Fuel $ 106 $ 98 $ 106 $ 98 $ 43 $ 42 $ 63 $ 56 Natural gas stored underground 35 41 35 41 35 41 — — Materials and supplies 191 164 109 109 44 44 65 65 Total $ 332 $ 303 $ 250 $ 248 $ 122 $ 127 $ 128 $ 121

Segment and Related Informati_2

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2019
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: 2019 2018 2017 Operating Revenues from external customers (a) U.K. Regulated $ 2,167 $ 2,268 $ 2,091 Kentucky Regulated 3,206 3,214 3,156 Pennsylvania Regulated 2,358 2,277 2,195 Corporate and Other 38 26 5 Total $ 7,769 $ 7,785 $ 7,447 Depreciation U.K. Regulated $ 250 $ 247 $ 230 Kentucky Regulated 547 475 439 Pennsylvania Regulated 386 352 309 Corporate and Other 16 20 30 Total $ 1,199 $ 1,094 $ 1,008 Amortization (b) U.K. Regulated $ 25 $ 34 $ 34 Kentucky Regulated 27 18 24 Pennsylvania Regulated 24 22 33 Corporate and Other 5 4 6 Total $ 81 $ 78 $ 97 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ 62 $ (190 ) $ 166 Kentucky Regulated 6 6 6 Corporate and Other 5 (2 ) 6 Total $ 73 $ (186 ) $ 178 Interest Expense U.K. Regulated $ 405 $ 413 $ 397 Kentucky Regulated 298 274 261 Pennsylvania Regulated 169 159 142 Corporate and Other 122 117 101 Total $ 994 $ 963 $ 901 Income Before Income Taxes U.K. Regulated $ 1,169 $ 1,339 $ 804 Kentucky Regulated 530 531 645 Pennsylvania Regulated 607 567 575 Corporate and Other (151 ) (152 ) (112 ) Total $ 2,155 $ 2,285 $ 1,912 Income Taxes (d) U.K. Regulated $ 192 $ 225 $ 152 Kentucky Regulated 94 120 359 Pennsylvania Regulated 149 136 216 Corporate and Other (26 ) (23 ) 57 Total $ 409 $ 458 $ 784 Deferred income taxes and investment tax credits (e) U.K. Regulated $ 140 $ 118 $ 66 Kentucky Regulated 82 94 294 Pennsylvania Regulated 90 125 257 Corporate and Other (3 ) 18 90 Total $ 309 $ 355 $ 707 2019 2018 2017 Net Income U.K. Regulated $ 977 $ 1,114 $ 652 Kentucky Regulated 436 411 286 Pennsylvania Regulated 458 431 359 Corporate and Other (125 ) (129 ) (169 ) Total $ 1,746 $ 1,827 $ 1,128 (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 17 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 and 2017. (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: 2019 2018 2017 Expenditures for long-lived assets U.K. Regulated $ 857 $ 954 $ 1,015 Kentucky Regulated 1,097 1,117 892 Pennsylvania Regulated 1,121 1,196 1,254 Corporate and Other 32 1 10 Total $ 3,107 $ 3,268 $ 3,171 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2019 2018 Total Assets U.K. Regulated (a) $ 17,622 $ 16,700 Kentucky Regulated 15,597 15,078 Pennsylvania Regulated 11,918 11,257 Corporate and Other (b) 543 361 Total $ 45,680 $ 43,396 (a) Includes $13.2 billion and $12.4 billion of net PP&E as of December 31, 2019 and December 31, 2018 . 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: 2019 2018 2017 Revenues from external customers U.K. $ 2,167 $ 2,268 $ 2,091 U.S. 5,602 5,517 5,356 Total $ 7,769 $ 7,785 $ 7,447
Long-lived Assets	As of December 31, 2019 2018 Long-Lived Assets U.K. $ 13,618 $ 12,791 U.S. 23,607 22,384 Total $ 37,225 $ 35,175 Geographic data for the years ended December 31 are as follows:

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Dec. 31, 2019
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: 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, 2019 and 2018 , PPL includes $2.2 billion and $2.3 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: 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 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 balances from contracts with customers that were impaired for the year ended December 31: 2019 2018 PPL $ 27 $ 34 PPL Electric 21 24 LKE 6 9 LG&E 2 4 KU 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, 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

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2019
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: 2019 2018 2017 Income (Numerator) Net income $ 1,746 $ 1,827 $ 1,128 Less amounts allocated to participating securities 1 2 2 Net income available to PPL common shareowners - Basic and Diluted $ 1,745 $ 1,825 $ 1,126 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 728,512 704,439 685,240 Add incremental non-participating securities: Share-based payment awards (a) 1,101 445 2,094 Forward sale agreements 7,141 3,735 — Weighted-average shares - Diluted EPS 736,754 708,619 687,334 Basic EPS Net Income available to PPL common shareowners $ 2.39 $ 2.59 $ 1.64 Diluted EPS Net Income available to PPL common shareowners $ 2.37 $ 2.58 $ 1.64 (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): 2019 Stock-based compensation plans (a) 1,936 DRIP 1,725 (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: 2019 2018 2017 Stock options — 172 696 Performance units 5 — — Restricted stock units 3 11 —

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
Income Taxes [Line Items]
Tax Reform	The Balance Sheets at December 31, 2017 reflected the increase to the Registrants' net regulatory liabilities as a result of the TCJA as follows: PPL PPL Electric LKE LG&E KU Net Increase in Regulatory Liabilities $ 2,185 $ 1,019 $ 1,166 $ 532 $ 634 PPL PPL Electric LKE LG&E KU Income tax expense (benefit) $ 220 $ (13 ) $ 112 $ — $ — 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 ) PPL PPL Electric LKE LG&E KU Income tax expense (benefit) $ 321 $ (13 ) $ 112 $ — $ —
Components of Income (Loss) Before Income Taxes	"Income Before Income Taxes" included the following: 2019 2018 2017 Domestic income $ 964 $ 1,127 $ 874 Foreign income 1,191 1,158 1,038 Total $ 2,155 $ 2,285 $ 1,912
Components of Deferred Tax Assets and Liabilities	Significant components of PPL's deferred income tax assets and liabilities were as follows: 2019 2018 Deferred Tax Assets Deferred investment tax credits $ 31 $ 31 Regulatory liabilities 75 87 Income taxes due to customer 462 479 Accrued pension and postretirement costs 211 277 Federal loss carryforwards 324 325 State loss carryforwards 432 419 Federal and state tax credit carryforwards 402 392 Foreign capital loss carryforwards 320 313 Foreign - other 8 10 Contributions in aid of construction 112 139 Domestic - other 99 88 Valuation allowances (834 ) (808 ) Total deferred tax assets 1,642 1,752 Deferred Tax Liabilities Domestic plant - net 3,546 3,359 Regulatory assets 262 314 Foreign plant - net 765 724 Foreign - pensions 72 83 Domestic - other 61 40 Total deferred tax liabilities 4,706 4,520 Net deferred tax liability $ 3,064 $ 2,768
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2019 , 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 carryforwards Federal net operating losses $ 1,499 $ 315 $ — 2032-2037 Federal charitable contributions 42 9 — 2020-2024 State net operating losses 5,879 432 (393 ) 2021-2039 State charitable contributions 1 — — 2020-2024 Foreign net operating losses 3 — — Indefinite Foreign capital losses 1,880 320 (320 ) Indefinite Federal - Other 7 1 — Indefinite Credit carryforwards Federal investment tax credit 133 — 2025-2039 Federal alternative minimum tax credit (a) 8 — Indefinite Federal foreign tax credits (b) 218 (113 ) 2024-2027 Federal - other 24 (6 ) 2020-2039 State Recycling Credit 18 — 2028 State - other 1 — Indefinite (a) The TCJA repealed the corporate alternative minimum tax (AMT) for tax years beginning after December 31, 2017. The existing indefinite carryforward period for AMT credits was retained. (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.
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	The changes in deferred tax valuation allowances were as follows: Additions Balance at Beginning of Period Charged to Income Charged to Other Accounts Deductions Balance at End of Period 2019 $ 808 $ 31 $ — $ 5 $ 834 2018 838 26 — 56 (a) 808 2017 593 256 (b) — 11 838 (a) 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. (b) Increase in valuation allowance of approximately $145 million related to expected future utilization of both 2017 foreign tax credits and pre-2017 foreign tax credits carried forward. For additional information, see the "Reconciliation of Income Tax Expense" and associated notes below. In addition, the reduction of the U.S. federal corporate income tax rate enacted by the TCJA in 2017 resulted in a $62 million increase in federal deferred tax assets and a corresponding valuation allowance related to the federal tax benefits of state net operating losses.
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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ (10 ) $ (19 ) $ 6 Current - State 19 17 25 Current - Foreign 91 104 45 Total Current Expense (Benefit) 100 102 76 Deferred - Federal (a) 139 203 532 Deferred - State 76 100 88 Deferred - Foreign 123 107 133 Total Deferred Expense (Benefit), excluding operating loss carryforwards 338 410 753 Amortization of investment tax credit (3 ) (3 ) (3 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 7 (20 ) (16 ) Deferred - State (33 ) (31 ) (26 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards (26 ) (51 ) (42 ) Total income tax expense (benefit) $ 409 $ 458 $ 784 Total income tax expense (benefit) - Federal $ 133 $ 161 $ 519 Total income tax expense (benefit) - State 62 86 87 Total income tax expense (benefit) - Foreign 214 211 178 Total income tax expense (benefit) $ 409 $ 458 $ 784 (a) Due to the enactment of the TCJA, PPL recorded the following in 2017: • $220 million of deferred income tax expense related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities; • $162 million of deferred tax expense related to the utilization of current year losses resulting from the taxable deemed dividend; partially offset by, $60 million of deferred tax benefits related to the $205 million of 2017 foreign tax credits partially offset by $145 million of valuation allowances. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2019 2018 2017 Other comprehensive income $ (93 ) $ (6 ) $ (34 ) Valuation allowance on state deferred taxes recorded to other comprehensive income — — (1 ) Total $ (93 ) $ (6 ) $ (35 )
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 453 $ 480 $ 669 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 45 40 46 Valuation allowance adjustments (b) 22 21 36 Impact of lower U.K. income tax rates (c) (25 ) (25 ) (176 ) U.S. income tax on foreign earnings - net of foreign tax credit (a)(d) 2 3 47 Foreign income return adjustments — — (8 ) Impact of the U.K. Finance Act on deferred tax balances (e) (14 ) (13 ) (16 ) Depreciation and other items not normalized (10 ) (11 ) (10 ) Amortization of excess deferred federal and state income taxes (f) (40 ) (37 ) — Interest benefit on U.K. financing entities (12 ) (17 ) (16 ) Deferred tax impact of U.S. tax reform (g) — — 220 Deferred tax impact of Kentucky tax reform (h) — 9 — Kentucky recycling credit, net of federal income tax expense (i) (18 ) — — Other 6 8 (8 ) Total increase (decrease) (44 ) (22 ) 115 Total income tax expense (benefit) $ 409 $ 458 $ 784 Effective income tax rate 19.0 % 20.0 % 41.0 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 2017, PPL recorded an increase in valuation allowances of $23 million primarily related to foreign tax credits recorded in 2016. The future utilization of these credits is expected to be lower as a result of the TCJA. In 2019, 2018 and 2017, PPL recorded deferred income tax expense of $25 million , $24 million and $16 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (c) The reduction in the U.S. federal corporate income tax rate from 35% to 21% significantly reduced the difference between the U.K. and U.S. income tax rates in 2019 and 2018 compared with 2017. (d) In 2017, PPL recorded a federal income tax benefit of $35 million primarily attributable to U.K. pension contributions. In 2017, PPL recorded deferred income tax expense of $83 million primarily related to enactment of the TCJA. The enacted tax law included a conversion from a worldwide tax system to a territorial tax system, effective January 1, 2018. In the transition to the territorial regime, a one-time transition tax was imposed on PPL’s unrepatriated accumulated foreign earnings in 2017. These earnings were treated as a taxable deemed dividend to PPL of approximately $462 million , including $205 million of foreign tax credits. As the PPL consolidated U.S. group had a taxable loss for 2017, inclusive of the taxable deemed dividend, these credits were recorded as a deferred tax asset. However, it is expected that under the TCJA, only $83 million of the $205 million of foreign tax credits will be realized in the carry forward period. Accordingly, a valuation allowance on the current year foreign tax credits in the amount of $122 million has been recorded to reflect the reduction in the future utilization of the credits. The foreign tax credits associated with the deemed repatriation result in a gross carryforward and corresponding deferred tax asset of $205 million offset by a valuation allowance of $122 million . (e) The U.K. Finance Act 2016, enacted in September 2016, reduced the U.K. statutory income tax rate effective April 1, 2020 to 17%. As a result, PPL reduced its net deferred tax liabilities each year as it revalued its balances at the 17% tax rate. (f) In 2019 and 2018, PPL recorded lower income tax expense for the amortization of excess deferred income 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. (g) In 2017, PPL recorded deferred income tax expense related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. 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. (h) 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, with the benefit recognized during the period in which the assets are placed into service. (i) In 2018, PPL filed its consolidated federal income tax return, which included updates to the TCJA provisional amounts recorded in 2017. The adjustments to the various provisional amounts that are considered complete as of the filed tax return resulted in an immaterial impact to income tax expense and are discussed in the TCJA section below. 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:
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: 2019 2018 2017 Taxes, other than income State gross receipts $ 107 $ 103 $ 102 State capital stock — — (6 ) Foreign property 127 134 127 Domestic Other 79 75 69 Total $ 313 $ 312 $ 292
Summary of Income Tax Examinations	With few exceptions, at December 31, 2019 , 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) 2015 and prior 2015 and prior 2015 and prior 2015 and prior 2015 and prior Pennsylvania (state) (a) 2015 and prior 2015 and prior Kentucky (state) 2014 and prior 2014 and prior 2014 and prior 2014 and prior U.K. (foreign) 2015 and prior (a) Tax year 2013 is still subject to examination.
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: 2019 2018 Deferred Tax Assets Accrued pension and postretirement costs $ 81 $ 110 Contributions in aid of construction 88 118 Regulatory liabilities 31 35 Income taxes due to customers 170 181 State loss carryforwards 6 14 Federal loss carryforwards 78 79 Other 23 25 Total deferred tax assets 477 562 2019 2018 Deferred Tax Liabilities Electric utility plant - net 1,761 1,681 Regulatory assets 139 176 Other 24 25 Total deferred tax liabilities 1,924 1,882 Net deferred tax liability $ 1,447 $ 1,320
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2019 , PPL Electric had the following loss carryforwards and related deferred tax assets: Gross Deferred Tax Asset Expiration Loss carryforwards Federal net operating losses $ 363 $ 76 2032-2037 Federal charitable contributions 9 2 2020-2024 State net operating losses 81 6 2031-2032
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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 44 $ 2 $ (65 ) Current - State 15 9 20 Total Current Expense (Benefit) 59 11 (45 ) Deferred - Federal (a) 51 96 234 Deferred - State 39 37 29 Total Deferred Expense (Benefit), excluding operating loss carryforwards 90 133 263 Tax expense (benefit) of operating loss carryforwards Deferred - Federal — (8 ) (5 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards — (8 ) (5 ) Total income tax expense (benefit) $ 149 $ 136 $ 213 Total income tax expense (benefit) - Federal $ 95 $ 90 $ 164 Total income tax expense (benefit) - State 54 46 49 Total income tax expense (benefit) $ 149 $ 136 $ 213 (a) Due to the enactment of the TCJA in 2017, PPL Electric recorded a $13 million deferred tax benefit related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities.
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: 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 127 $ 119 $ 201 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 47 43 36 Depreciation and other items not normalized (10 ) (11 ) (8 ) Amortization of excess deferred federal income taxes (b) (18 ) (17 ) — Deferred tax impact of U.S. tax reform (c) — — (13 ) Other 3 2 (3 ) Total increase (decrease) 22 17 12 Total income tax expense (benefit) $ 149 $ 136 $ 213 Effective income tax rate 24.6 % 24.0 % 37.0 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 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. (c) In 2017, PPL Electric recorded a deferred tax benefit related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.
Details of Taxes Other Than Income	2019 2018 2017 Taxes, other than income State gross receipts $ 107 $ 103 $ 102 Property and other 5 6 5 Total $ 112 $ 109 $ 107 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:
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: 2019 2018 Deferred Tax Assets Federal loss carryforwards $ 140 $ 142 State loss carryforwards 31 33 Federal tax credit carryforwards 162 169 Contributions in aid of construction 23 21 Regulatory liabilities 44 52 Accrued pension and postretirement costs 71 92 State tax credit carryforwards 19 1 Income taxes due to customers 292 299 Deferred investment tax credits 31 32 Lease liabilities 14 — Valuation allowances (6 ) (8 ) Other 28 28 Total deferred tax assets 849 861 Deferred Tax Liabilities Plant - net 1,778 1,671 Regulatory assets 122 138 Lease right-of-use assets 12 — Other 6 8 Total deferred tax liabilities 1,918 1,817 Net deferred tax liability $ 1,069 $ 956
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2019 , 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 $ 668 $ 140 $ — 2032 - 2037 Federal charitable contributions 23 5 — 2020 - 2024 State net operating losses 797 31 — 2029 - 2038 Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal investment tax credit 133 — 2025 - 2028, 2036 - 2039 Federal alternative minimum tax credit (a) 7 — Indefinite Federal - other 22 (6 ) 2020-2039 State - recycling credit 18 — 2028 State - other 1 — Indefinite (a) The TCJA repealed the corporate alternative minimum tax (AMT) for tax years beginning after December 31, 2017. The existing indefinite carryforward period for AMT credits was retained.
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	Changes in deferred tax valuation allowances were: Balance at Beginning of Period Additions Deductions Balance at End of Period 2019 $ 8 $ 3 $ 5 (a) $ 6 2018 8 — — 8 2017 11 4 7 (a) 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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 20 $ 31 $ 74 Current - State — 4 6 Total Current Expense (Benefit) 20 35 80 Deferred - Federal (a) 81 65 268 Deferred - State (b) 5 34 32 Total Deferred Expense (Benefit), excluding benefits of operating loss carryforwards 86 99 300 Amortization of investment tax credit - Federal (3 ) (3 ) (3 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal — (2 ) (2 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards — (2 ) (2 ) Total income tax expense (benefit) (c) $ 103 $ 129 $ 375 Total income tax expense (benefit) - Federal $ 98 $ 91 $ 337 Total income tax expense (benefit) - State 5 38 38 Total income tax expense (benefit) (c) $ 103 $ 129 $ 375 (a) Due to the enactment of the TCJA in 2017, LKE recorded $112 million of deferred income tax expense, of which $108 million related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities and $4 million related to valuation allowances on tax credits expiring in 2021. (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 (c) Excludes deferred federal and state tax expense (benefit) recorded to OCI of $(1) million in 2019 , $5 million in 2018 and $(10) million in 2017 .
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 120 $ 121 $ 242 Increase (decrease) due to: State income taxes, net of federal income tax benefit 23 22 26 Amortization of investment tax credit (3 ) (3 ) (3 ) Amortization of excess deferred federal and state income taxes (b) (23 ) (20 ) (2 ) Deferred tax impact of U.S. tax reform (c) — — 112 Deferred tax impact of state tax reform (d) — 9 — Kentucky Recycling Credit, net of federal income tax expense (e) (18 ) — — Other 4 — — Total increase (decrease) (17 ) 8 133 Total income tax expense (benefit) $ 103 $ 129 $ 375 Effective income tax rate 18.0 % 22.5 % 54.3 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 2019 and 2018, LKE recorded lower income tax expense for the amortization of excess deferred income 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. (c) In 2017, LKE recorded deferred income tax expense primarily due to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. (d) 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. (e) 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. 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:
Details of Taxes Other Than Income	2019 2018 2017 Taxes, other than income Property and other $ 74 $ 70 $ 65 Total $ 74 $ 70 $ 65 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:
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: 2019 2018 Deferred Tax Assets Contributions in aid of construction $ 15 $ 14 Regulatory liabilities 19 24 Accrued pension and postretirement costs 6 16 Deferred investment tax credits 8 9 Income taxes due to customers 136 139 State tax credit carryforwards 14 — Lease liabilities 5 — Valuation allowances (14 ) — Other 10 15 Total deferred tax assets 199 217 2019 2018 Deferred Tax Liabilities Plant - net 811 751 Regulatory assets 77 88 Lease right-of-use assets 4 — Other 4 6 Total deferred tax liabilities 896 845 Net deferred tax liability $ 697 $ 628
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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 4 $ — $ — Current - State 4 4 5 Total Current Expense (Benefit) 8 4 5 Deferred - Federal 46 51 112 Deferred - State 10 10 14 Total Deferred Expense (Benefit), excluding benefits of operating loss carryforwards 56 61 126 Amortization of investment tax credit - Federal (1 ) (1 ) (1 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal — — 1 Total Tax Expense (Benefit) of Operating Loss Carryforwards — — 1 Total income tax expense (benefit) $ 63 $ 64 $ 131 Total income tax expense (benefit) - Federal $ 49 $ 50 $ 112 Total income tax expense (benefit) - State 14 14 19 Total income tax expense (benefit) $ 63 $ 64 $ 131
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: 2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 62 $ 62 $ 120 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 11 14 Amortization of excess deferred federal and state income taxes (b) (10 ) (8 ) (1 ) Kentucky recycling credit, net of federal income tax expense (c) (14 ) — — Valuation allowance adjustments (c) 14 — — Other (1 ) (1 ) (2 ) Total increase (decrease) 1 2 11 Total income tax expense (benefit) $ 63 $ 64 $ 131 Effective income tax rate 21.4 % 21.5 % 38.1 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) In 2019 and 2018, LG&E recorded lower income tax expense for the amortization of excess deferred income 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. (c) In 2019, LG&E recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky. This amount has been reserved due to insufficient Kentucky taxable income projected at LG&E.
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: 2019 2018 2017 Taxes, other than income Property and other $ 39 $ 36 $ 33 Total $ 39 $ 36 $ 33
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: 2019 2018 Deferred Tax Assets Contributions in aid of construction $ 8 $ 7 Regulatory liabilities 25 28 Accrued pension and postretirement costs — 7 Deferred investment tax credits 23 23 Income taxes due to customers 156 160 State tax credit carryforwards 5 — Lease liabilities 8 — Valuation allowances (4 ) — Other 3 3 Total deferred tax assets 224 228 Deferred Tax Liabilities Plant - net 959 911 Regulatory assets 45 50 Accrued pension and postretirement costs 2 — Lease right-of-use assets 7 — Other 3 2 Total deferred tax liabilities 1,016 963 Net deferred tax liability $ 792 $ 735
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: 2019 2018 2017 Income Tax Expense (Benefit) Current - Federal $ 35 $ 22 $ — Current - State 5 6 7 Total Current Expense (Benefit) 40 28 7 Deferred - Federal 28 40 138 Deferred - State 13 10 16 Total Deferred Expense (Benefit) 41 50 154 Amortization of investment tax credit - Federal (2 ) (2 ) (2 ) Total income tax expense (benefit) $ 79 $ 76 $ 159 Total income tax expense (benefit) - Federal $ 61 $ 60 $ 136 Total income tax expense (benefit) - State 18 16 23 Total income tax expense (benefit) $ 79 $ 76 $ 159
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	2019 2018 2017 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 78 $ 76 $ 146 Increase (decrease) due to: State income taxes, net of federal income tax benefit 15 13 15 Amortization of investment tax credit (2 ) (2 ) (2 ) Amortization of excess deferred federal and state income taxes (b) (13 ) (12 ) (1 ) Kentucky recycling credit, net of federal income tax expense (c) (4 ) — — Valuation allowance adjustments (c) 4 — — Other 1 1 1 Total increase (decrease) 1 — 13 Total income tax expense (benefit) $ 79 $ 76 $ 159 Effective income tax rate 21.2 % 21.0 % 38.0 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018 . (b) In 2019 and 2018, KU recorded lower income tax expense for the amortization of excess deferred income 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. (c) In 2019, KU 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 KU. 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:
Details of Taxes Other Than Income	2019 2018 2017 Taxes, other than income Property and other $ 35 $ 34 $ 32 Total $ 35 $ 34 $ 32 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:

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2019
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 2019 2018 2019 2018 Current Regulatory Assets: Gas supply clause $ 8 $ 12 $ — $ — Smart meter rider 13 11 13 11 Plant outage costs 32 10 — — Transmission formula rate — — 3 — Transmission service charge 10 — 10 — Other 4 3 — — Total current regulatory assets (a) $ 67 $ 36 $ 26 $ 11 Noncurrent Regulatory Assets: Defined benefit plans $ 800 $ 963 $ 467 $ 558 Storm costs 39 56 15 22 Unamortized loss on debt 41 45 18 22 Interest rate swaps 22 20 — — Terminated interest rate swaps 81 87 — — Accumulated cost of removal of utility plant 220 200 220 200 AROs 279 273 — — Act 129 compliance rider 6 19 6 19 Other 4 10 — 3 Total noncurrent regulatory assets $ 1,492 $ 1,673 $ 726 $ 824 PPL PPL Electric 2019 2018 2019 2018 Current Regulatory Liabilities: Generation supply charge $ 23 $ 33 $ 23 $ 33 Transmission service charge — — — 3 Environmental cost recovery 5 16 — — Universal service rider 9 27 9 27 Transmission formula rate — — — 3 Fuel adjustment clause 8 — — — TCJA customer refund 61 20 59 3 Storm damage expense rider 5 5 5 5 Generation formula rate 1 7 — — Other 3 14 — — Total current regulatory liabilities $ 115 $ 122 $ 96 $ 74 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 640 $ 674 $ — $ — Power purchase agreement - OVEC 51 59 — — Net deferred taxes 1,756 1,826 588 629 Defined benefit plans 51 37 11 5 Terminated interest rate swaps 68 72 — — TCJA customer refund — 41 — 41 Other 6 5 — — Total noncurrent regulatory liabilities $ 2,572 $ 2,714 $ 599 $ 675 LKE LG&E KU 2019 2018 2019 2018 2019 2018 Current Regulatory Assets: Plant outage costs $ 32 $ 10 $ 16 $ 7 $ 16 $ 3 Gas supply clause 8 12 8 12 — — Other 1 3 1 2 — 1 Total current regulatory assets $ 41 $ 25 $ 25 $ 21 $ 16 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 333 $ 405 $ 206 $ 249 $ 127 $ 156 Storm costs 24 34 14 20 10 14 Unamortized loss on debt 23 23 14 15 9 8 Interest rate swaps 22 20 22 20 — — Terminated interest rate swaps 81 87 47 51 34 36 AROs 279 273 76 75 203 198 Other 4 7 1 1 3 6 Total noncurrent regulatory assets $ 766 $ 849 $ 380 $ 431 $ 386 $ 418 LKE LG&E KU 2019 2018 2019 2018 2019 2018 Current Regulatory Liabilities: Environmental cost recovery $ 5 $ 16 $ 1 $ 6 $ 4 $ 10 Fuel adjustment clauses 8 — — — 8 — TCJA customer refund 2 17 — 7 2 10 Generation formula rate 1 7 — — 1 7 Other 3 8 1 4 2 4 Total current regulatory liabilities $ 19 $ 48 $ 2 $ 17 $ 17 $ 31 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 640 $ 674 $ 266 $ 279 $ 374 $ 395 Power purchase agreement - OVEC 51 59 35 41 16 18 Net deferred taxes 1,168 1,197 544 557 624 640 Defined benefit plans 40 32 — — 40 32 Terminated interest rate swaps 68 72 34 36 34 36 Other 6 5 4 2 2 3 Total noncurrent regulatory liabilities $ 1,973 $ 2,039 $ 883 $ 915 $ 1,090 $ 1,124 (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, 2019
Debt Disclosure [Line Items]
Credit Facilities in Place at Period End	The following credit facilities were in place at: December 31, 2019 December 31, 2018 Expiration Date Capacity Borrowed Letters of Credit and Commercial Paper Issued Unused Capacity Borrowed Letters of Credit and Commercial Paper Issued PPL U.K. WPD plc Syndicated Credit Facility (a)(b)(c) Jan. 2023 £ 210 £ 155 £ — £ 55 £ 157 £ — WPD (South West) Syndicated Credit Facility (a)(b)(c) July 2021 245 40 — 205 — — WPD (East Midlands) Syndicated Credit Facility (a)(b)(c) July 2021 300 — — 300 38 — WPD (West Midlands) Syndicated Credit Facility (a)(b)(c) July 2021 300 48 — 252 — — Uncommitted Credit Facilities 100 — 4 96 — 4 Total U.K. Credit Facilities (b) £ 1,155 £ 243 £ 4 £ 908 £ 195 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Jan 2024 $ 1,450 $ 450 $ 1,000 $ — $ 669 Bilateral Credit Facility (c) (d) Mar 2020 100 — 15 85 — 15 Total PPL Capital Funding Credit Facilities $ 1,550 $ — $ 465 $ 1,085 $ — $ 684 PPL Electric Syndicated Credit Facility (c) (d) Jan 2024 $ 650 $ — $ 1 $ 649 $ — $ 1 December 31, 2019 December 31, 2018 Expiration Date Capacity Borrowed Letters of Credit and Commercial Paper Issued Unused Capacity Borrowed Letters of Credit and Commercial Paper Issued LG&E Syndicated Credit Facility (c) (d) Jan 2024 $ 500 $ — $ 238 $ 262 $ — $ 279 Term Loan Credit Facility (c) (e) — — — — 200 — Total LG&E Credit Facilities $ 500 $ — $ 238 $ 262 $ 200 $ 279 KU Syndicated Credit Facility (c) (d) Jan 2024 $ 400 $ — $ 150 $ 250 $ — $ 235 Letter of Credit Facility (f) — — — — — 198 Total KU Credit Facilities $ 400 $ — $ 150 $ 250 $ — $ 433 (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, 2019 and 2018 included USD-denominated borrowings of $200 million for both periods, which bore interest at 2.52% and 3.17% . The WPD (South West) amount borrowed at December 31, 2019 was a GBP-denominated borrowing, which equated to $51 million and bore interest at 1.09% . The WPD (East Midlands) amount borrowed at December 31, 2018 was a GBP- denominated borrowing which equated to $48 million and bore interest at 1.12% . The WPD (West Midlands) amount borrowed at December 31, 2019 was a GBP-denominated borrowing, which equated to $62 million and bore interest at 1.11% . At December 31, 2019 , the unused capacity under the U.K. credit facilities was approximately $1.2 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 2020 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. (e) LG&E entered into a $200 million term loan credit agreement in October 2017. All borrowings were repaid and the facility expired in 2019. The outstanding borrowings at December 31, 2018 bore interest at an average rate of 2.97% . (f) KU's letter of credit facility was terminated in September 2019 in connection with the bond remarketings discussed below.
Commercial paper	The following commercial paper programs were in place at: December 31, 2019 December 31, 2018 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding 2.13% $ 1,500 $ 450 $ 1,050 2.82% $ 669 PPL Electric 650 — 650 — LG&E 2.07% 350 238 112 2.94% 279 KU 2.02% 350 150 200 2.94% 235 Total $ 2,850 $ 838 $ 2,012 $ 1,183
Long-term Debt	Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (g) 2019 2018 PPL U.S. Senior Unsecured Notes 3.88 % 2020 - 2047 $ 4,325 $ 4,325 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.95 % 2020 - 2049 8,705 7,705 Junior Subordinated Notes 5.24 % 2067 - 2073 930 930 Term Loan Credit Facility 2019 — 200 Total U.S. Long-term Debt 13,960 13,160 U.K. Senior Unsecured Notes (d) 4.97 % 2020 - 2040 6,874 6,471 Index-linked Senior Unsecured Notes (e) 1.45 % 2026 - 2056 1,104 1,063 Term Loan Credit Facility 2.18 % 2024 - 2024 64 — Total U.K. Long-term Debt (f) 8,042 7,534 Total Long-term Debt Before Adjustments 22,002 20,694 Fair market value adjustments 12 16 Unamortized premium and (discount), net 5 9 Unamortized debt issuance costs (126 ) (120 ) Total Long-term Debt 21,893 20,599 Less current portion of Long-term Debt 1,172 530 Total Long-term Debt, noncurrent $ 20,721 $ 20,069 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.08 % 2021 - 2049 $ 4,039 $ 3,739 Total Long-term Debt Before Adjustments 4,039 3,739 Unamortized discount (24 ) (18 ) Unamortized debt issuance costs (30 ) (27 ) Total Long-term Debt 3,985 3,694 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 3,985 $ 3,694 LKE Senior Unsecured Notes 3.97 % 2020 - 2021 $ 725 $ 725 Term Loan Credit Facility — 200 First Mortgage Bonds (a) (c) 3.84 % 2020 - 2049 4,666 3,966 Long-term debt to affiliate 3.69 % 2026 - 2028 650 650 Total Long-term Debt Before Adjustments 6,041 5,541 Unamortized premium 5 — Unamortized discount (12 ) (13 ) Unamortized debt issuance costs (32 ) (26 ) Total Long-term Debt 6,002 5,502 Less current portion of Long-term Debt 975 530 Total Long-term Debt, noncurrent $ 5,027 $ 4,972 December 31, Weighted-Average Maturities (g) 2019 2018 LG&E Term Loan Credit Facility $ — $ 200 First Mortgage Bonds (a) (c) 3.73 % 2025 - 2049 2,024 1,624 Total Long-term Debt Before Adjustments 2,024 1,824 Unamortized discount (4 ) (4 ) Unamortized debt issuance costs (15 ) (11 ) Total Long-term Debt 2,005 1,809 Less current portion of Long-term Debt — 434 Total Long-term Debt, noncurrent $ 2,005 $ 1,375 KU First Mortgage Bonds (a) (c) 3.93 % 2020 - 2045 $ 2,642 $ 2,342 Total Long-term Debt Before Adjustments 2,642 2,342 Unamortized premium 5 — Unamortized discount (8 ) (8 ) Unamortized debt issuance costs (16 ) (13 ) Total Long-term Debt 2,623 2,321 Less current portion of Long-term Debt 500 96 Total Long-term Debt, noncurrent $ 2,123 $ 2,225 (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 $10.1 billion and $9.4 billion at December 31, 2019 and 2018 . 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 $5.3 billion and $5.1 billion at December 31, 2019 and 2018 . 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 $6.6 billion and $6.3 billion at December 31, 2019 and 2018 . (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 that may be redeemed, in whole or in part, at par beginning in October 2020, and are 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. (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, 2019 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $700 million for LKE, comprised of $392 million and $308 million for LG&E and KU respectively. At December 31, 2019 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $181 million for LKE, comprised of $148 million and $33 million for LG&E 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 ( $291 million at December 31, 2019 ) 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 2018 to 2019 was an increase of approximately £20 million ( $26 million ) resulting from inflation. In addition, this amount includes £327 million ( $423 million at December 31, 2019 ) 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 £5.7 billion ( $7.4 billion at December 31, 2019 ) 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, 2019 .
Long-term Debt Maturities	The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2020 through 2024 and thereafter are as follows: PPL PPL Electric LKE LG&E KU 2020 $ 1,169 $ — $ 975 $ — $ 500 2021 1,574 400 674 292 132 2022 1,274 474 — — — 2023 2,254 90 13 — 13 2024 932 — — — — Thereafter 14,799 3,075 4,379 1,732 1,997 Total $ 22,002 $ 4,039 $ 6,041 $ 2,024 $ 2,642

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	At December 31, 2019 , PPL, LKE, LG&E and KU expect to receive the following fixed lease payments over the remaining term of their operating lease agreements: PPL LKE LG&E KU 2020 $ 13 $ 7 $ — $ 7 2021 11 5 — 5 2022 5 — — — 2023 5 1 — — 2024 3 — — — Thereafter 12 — — — Total $ 49 $ 13 $ — $ 12 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 year ended December 31, 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, 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, 2019 . PPL LKE LG&E KU 2020 $ 29 $ 18 $ 7 $ 11 2021 22 13 5 8 2022 17 9 4 5 2023 15 7 3 4 2024 12 6 2 4 Thereafter 27 8 3 4 Total $ 122 $ 61 $ 24 $ 36 Weighted-average discount rate 3.48 % 3.96 % 3.89 % 4.01 % Weighted-average remaining lease term (in years) 8 5 5 5 Current lease liabilities (a) $ 26 $ 16 $ 6 $ 10 Non-current lease liabilities (a) 78 39 15 23 Right-of-use assets (b) 96 47 18 28 (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. At December 31, 2018, the total future minimum rental payments for all operating leases were estimated to be: PPL LKE LG&E KU 2019 $ 26 $ 20 $ 10 $ 10 2020 21 15 6 9 2021 15 11 4 7 2022 13 7 3 4 2023 8 6 3 3 Thereafter 33 11 4 6 Total $ 116 $ 70 $ 30 $ 39
LG And E And KU Energy LLC [Member]
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	At December 31, 2019 , PPL, LKE, LG&E and KU expect to receive the following fixed lease payments over the remaining term of their operating lease agreements: PPL LKE LG&E KU 2020 $ 13 $ 7 $ — $ 7 2021 11 5 — 5 2022 5 — — — 2023 5 1 — — 2024 3 — — — Thereafter 12 — — — Total $ 49 $ 13 $ — $ 12 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 year ended December 31, 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, 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, 2019 . PPL LKE LG&E KU 2020 $ 29 $ 18 $ 7 $ 11 2021 22 13 5 8 2022 17 9 4 5 2023 15 7 3 4 2024 12 6 2 4 Thereafter 27 8 3 4 Total $ 122 $ 61 $ 24 $ 36 Weighted-average discount rate 3.48 % 3.96 % 3.89 % 4.01 % Weighted-average remaining lease term (in years) 8 5 5 5 Current lease liabilities (a) $ 26 $ 16 $ 6 $ 10 Non-current lease liabilities (a) 78 39 15 23 Right-of-use assets (b) 96 47 18 28 (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. At December 31, 2018, the total future minimum rental payments for all operating leases were estimated to be: PPL LKE LG&E KU 2019 $ 26 $ 20 $ 10 $ 10 2020 21 15 6 9 2021 15 11 4 7 2022 13 7 3 4 2023 8 6 3 3 Thereafter 33 11 4 6 Total $ 116 $ 70 $ 30 $ 39
Louisville Gas And Electric Co [Member]
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	At December 31, 2019 , PPL, LKE, LG&E and KU expect to receive the following fixed lease payments over the remaining term of their operating lease agreements: PPL LKE LG&E KU 2020 $ 13 $ 7 $ — $ 7 2021 11 5 — 5 2022 5 — — — 2023 5 1 — — 2024 3 — — — Thereafter 12 — — — Total $ 49 $ 13 $ — $ 12 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 year ended December 31, 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, 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, 2019 . PPL LKE LG&E KU 2020 $ 29 $ 18 $ 7 $ 11 2021 22 13 5 8 2022 17 9 4 5 2023 15 7 3 4 2024 12 6 2 4 Thereafter 27 8 3 4 Total $ 122 $ 61 $ 24 $ 36 Weighted-average discount rate 3.48 % 3.96 % 3.89 % 4.01 % Weighted-average remaining lease term (in years) 8 5 5 5 Current lease liabilities (a) $ 26 $ 16 $ 6 $ 10 Non-current lease liabilities (a) 78 39 15 23 Right-of-use assets (b) 96 47 18 28 (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. At December 31, 2018, the total future minimum rental payments for all operating leases were estimated to be: PPL LKE LG&E KU 2019 $ 26 $ 20 $ 10 $ 10 2020 21 15 6 9 2021 15 11 4 7 2022 13 7 3 4 2023 8 6 3 3 Thereafter 33 11 4 6 Total $ 116 $ 70 $ 30 $ 39
Kentucky Utilities Co [Member]
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	At December 31, 2019 , PPL, LKE, LG&E and KU expect to receive the following fixed lease payments over the remaining term of their operating lease agreements: PPL LKE LG&E KU 2020 $ 13 $ 7 $ — $ 7 2021 11 5 — 5 2022 5 — — — 2023 5 1 — — 2024 3 — — — Thereafter 12 — — — Total $ 49 $ 13 $ — $ 12 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 year ended December 31, 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, 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, 2019 . PPL LKE LG&E KU 2020 $ 29 $ 18 $ 7 $ 11 2021 22 13 5 8 2022 17 9 4 5 2023 15 7 3 4 2024 12 6 2 4 Thereafter 27 8 3 4 Total $ 122 $ 61 $ 24 $ 36 Weighted-average discount rate 3.48 % 3.96 % 3.89 % 4.01 % Weighted-average remaining lease term (in years) 8 5 5 5 Current lease liabilities (a) $ 26 $ 16 $ 6 $ 10 Non-current lease liabilities (a) 78 39 15 23 Right-of-use assets (b) 96 47 18 28 (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. At December 31, 2018, the total future minimum rental payments for all operating leases were estimated to be: PPL LKE LG&E KU 2019 $ 26 $ 20 $ 10 $ 10 2020 21 15 6 9 2021 15 11 4 7 2022 13 7 3 4 2023 8 6 3 3 Thereafter 33 11 4 6 Total $ 116 $ 70 $ 30 $ 39

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2019
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 Total As % of Outstanding Annual Grant Annual Grant Limit For Individual Participants - Performance Based Awards Award Limit PPL Common Stock On First Day of Limit Options For awards denominated in For awards denominated in 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: 2019 2018 2017 PPL $ 31.95 $ 30.58 $ 35.30 PPL Electric 32.33 30.00 35.45 LKE 30.65 30.98 35.25
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2019 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,098,203 $ 33.45 Granted 479,428 31.95 Vested (429,258 ) 33.64 Forfeited (10,688 ) 31.53 Nonvested, end of period 1,137,685 32.76 PPL Electric Nonvested, beginning of period 187,337 $ 33.09 Transfer between registrants (3,305 ) 33.06 Granted 112,138 32.33 Vested (59,661 ) 33.77 Forfeited (6,649 ) 31.01 Nonvested, end of period 229,860 32.61 LKE Nonvested, beginning of period 133,030 $ 33.45 Granted 76,256 30.65 Vested (42,841 ) 33.75 Nonvested, end of period 166,445 32.09
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: 2019 2018 2017 PPL $ 13 $ 16 $ 20 PPL Electric 2 2 3 LKE 1 5 4
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2019 2018 2017 Expected stock volatility 17.57 % 17.60 % 17.40 % 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: 2019 2018 2017 PPL $ 35.83 $ 38.26 $ 38.38 PPL Electric 35.68 38.37 38.37 LKE 35.93 38.32 38.24 The weighted-average grant date fair value of ROE performance units granted was: 2019 2018 2017 PPL $ 30.89 $ 32.21 $ 32.42 PPL Electric 30.76 32.32 34.41 LKE 30.99 32.28 34.29
Performance Units, Activity Rollforward	TSR performance unit activity for 2019 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 840,124 $ 37.89 Granted 250,734 35.83 Forfeited (a) (351,466 ) 37.24 Nonvested, end of period 739,392 37.50 PPL Electric Nonvested, beginning of period 67,863 $ 37.86 Granted 24,158 35.68 Forfeited (a) (25,222 ) 36.92 Nonvested, end of period 66,799 37.43 LKE Nonvested, beginning of period 148,996 $ 37.81 Granted 39,453 35.93 Forfeited (a) (57,916 ) 37.02 Nonvested, end of period 130,533 37.60 (a) Primarily related to the forfeiture of 2016 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2019 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 328,958 $ 32.86 Granted 241,807 30.89 Nonvested, end of period 570,765 32.02 PPL Electric Nonvested, beginning of period 25,960 $ 32.96 Granted 23,234 30.76 Nonvested, end of period 49,194 31.92 LKE Nonvested, beginning of period 69,620 $ 32.87 Granted 38,185 30.99 Nonvested, end of period 107,805 32.20
Stock Options, Activity Rollforward	Stock option activity for 2019 was: Number of Options Weighted Average Exercise Price Per Share Weighted- Average Remaining Contractual Term (years) Aggregate Total Intrinsic Value PPL Outstanding at beginning of period 2,914,525 $ 26.26 Exercised (1,578,554 ) 26.31 Forfeited (5,028 ) 28.77 Outstanding and exercisable at end of period 1,330,943 26.20 2.5 $ 13
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	2019 2018 2017 PPL $ 35 $ 25 $ 32 PPL Electric 12 10 18 LKE 9 8 8 The income tax benefit related to above compensation expense was as follows: 2019 2018 2017 PPL $ 10 $ 10 $ 13 PPL Electric 3 3 8 LKE 2 2 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2019 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 14 1.9 PPL Electric 3 2.2 LKE 1 1.5
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 Total As % of Outstanding Annual Grant Annual Grant Limit For Individual Participants - Performance Based Awards Award Limit PPL Common Stock On First Day of Limit Options For awards denominated in For awards denominated in 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: 2019 2018 2017 PPL $ 31.95 $ 30.58 $ 35.30 PPL Electric 32.33 30.00 35.45 LKE 30.65 30.98 35.25
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2019 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,098,203 $ 33.45 Granted 479,428 31.95 Vested (429,258 ) 33.64 Forfeited (10,688 ) 31.53 Nonvested, end of period 1,137,685 32.76 PPL Electric Nonvested, beginning of period 187,337 $ 33.09 Transfer between registrants (3,305 ) 33.06 Granted 112,138 32.33 Vested (59,661 ) 33.77 Forfeited (6,649 ) 31.01 Nonvested, end of period 229,860 32.61 LKE Nonvested, beginning of period 133,030 $ 33.45 Granted 76,256 30.65 Vested (42,841 ) 33.75 Nonvested, end of period 166,445 32.09
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: 2019 2018 2017 PPL $ 13 $ 16 $ 20 PPL Electric 2 2 3 LKE 1 5 4
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2019 2018 2017 Expected stock volatility 17.57 % 17.60 % 17.40 % 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: 2019 2018 2017 PPL $ 35.83 $ 38.26 $ 38.38 PPL Electric 35.68 38.37 38.37 LKE 35.93 38.32 38.24 The weighted-average grant date fair value of ROE performance units granted was: 2019 2018 2017 PPL $ 30.89 $ 32.21 $ 32.42 PPL Electric 30.76 32.32 34.41 LKE 30.99 32.28 34.29
Performance Units, Activity Rollforward	ROE performance unit activity for 2019 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 328,958 $ 32.86 Granted 241,807 30.89 Nonvested, end of period 570,765 32.02 PPL Electric Nonvested, beginning of period 25,960 $ 32.96 Granted 23,234 30.76 Nonvested, end of period 49,194 31.92 LKE Nonvested, beginning of period 69,620 $ 32.87 Granted 38,185 30.99 Nonvested, end of period 107,805 32.20 TSR performance unit activity for 2019 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 840,124 $ 37.89 Granted 250,734 35.83 Forfeited (a) (351,466 ) 37.24 Nonvested, end of period 739,392 37.50 PPL Electric Nonvested, beginning of period 67,863 $ 37.86 Granted 24,158 35.68 Forfeited (a) (25,222 ) 36.92 Nonvested, end of period 66,799 37.43 LKE Nonvested, beginning of period 148,996 $ 37.81 Granted 39,453 35.93 Forfeited (a) (57,916 ) 37.02 Nonvested, end of period 130,533 37.60 (a) Primarily related to the forfeiture of 2016 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout.
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	2019 2018 2017 PPL $ 35 $ 25 $ 32 PPL Electric 12 10 18 LKE 9 8 8 The income tax benefit related to above compensation expense was as follows: 2019 2018 2017 PPL $ 10 $ 10 $ 13 PPL Electric 3 3 8 LKE 2 2 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2019 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 14 1.9 PPL Electric 3 2.2 LKE 1 1.5
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 Total As % of Outstanding Annual Grant Annual Grant Limit For Individual Participants - Performance Based Awards Award Limit PPL Common Stock On First Day of Limit Options For awards denominated in For awards denominated in 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: 2019 2018 2017 PPL $ 31.95 $ 30.58 $ 35.30 PPL Electric 32.33 30.00 35.45 LKE 30.65 30.98 35.25
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2019 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,098,203 $ 33.45 Granted 479,428 31.95 Vested (429,258 ) 33.64 Forfeited (10,688 ) 31.53 Nonvested, end of period 1,137,685 32.76 PPL Electric Nonvested, beginning of period 187,337 $ 33.09 Transfer between registrants (3,305 ) 33.06 Granted 112,138 32.33 Vested (59,661 ) 33.77 Forfeited (6,649 ) 31.01 Nonvested, end of period 229,860 32.61 LKE Nonvested, beginning of period 133,030 $ 33.45 Granted 76,256 30.65 Vested (42,841 ) 33.75 Nonvested, end of period 166,445 32.09
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: 2019 2018 2017 PPL $ 13 $ 16 $ 20 PPL Electric 2 2 3 LKE 1 5 4
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2019 2018 2017 Expected stock volatility 17.57 % 17.60 % 17.40 % 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: 2019 2018 2017 PPL $ 35.83 $ 38.26 $ 38.38 PPL Electric 35.68 38.37 38.37 LKE 35.93 38.32 38.24 The weighted-average grant date fair value of ROE performance units granted was: 2019 2018 2017 PPL $ 30.89 $ 32.21 $ 32.42 PPL Electric 30.76 32.32 34.41 LKE 30.99 32.28 34.29
Performance Units, Activity Rollforward	ROE performance unit activity for 2019 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 328,958 $ 32.86 Granted 241,807 30.89 Nonvested, end of period 570,765 32.02 PPL Electric Nonvested, beginning of period 25,960 $ 32.96 Granted 23,234 30.76 Nonvested, end of period 49,194 31.92 LKE Nonvested, beginning of period 69,620 $ 32.87 Granted 38,185 30.99 Nonvested, end of period 107,805 32.20 TSR performance unit activity for 2019 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 840,124 $ 37.89 Granted 250,734 35.83 Forfeited (a) (351,466 ) 37.24 Nonvested, end of period 739,392 37.50 PPL Electric Nonvested, beginning of period 67,863 $ 37.86 Granted 24,158 35.68 Forfeited (a) (25,222 ) 36.92 Nonvested, end of period 66,799 37.43 LKE Nonvested, beginning of period 148,996 $ 37.81 Granted 39,453 35.93 Forfeited (a) (57,916 ) 37.02 Nonvested, end of period 130,533 37.60 (a) Primarily related to the forfeiture of 2016 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout.
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	2019 2018 2017 PPL $ 35 $ 25 $ 32 PPL Electric 12 10 18 LKE 9 8 8 The income tax benefit related to above compensation expense was as follows: 2019 2018 2017 PPL $ 10 $ 10 $ 13 PPL Electric 3 3 8 LKE 2 2 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2019 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 14 1.9 PPL Electric 3 2.2 LKE 1 1.5

Retirement and Postemployment_2

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2019
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 2019 2018 2017 2019 2018 2017 2019 2018 2017 Net periodic defined benefit costs (credits): Service cost $ 50 $ 62 $ 65 $ 68 $ 82 $ 76 $ 6 $ 7 $ 7 Interest cost 164 156 168 187 185 178 22 21 23 Expected return on plan assets (245 ) (249 ) (231 ) (588 ) (587 ) (514 ) (18 ) (23 ) (22 ) Amortization of: Prior service cost (credit) 8 10 10 1 — — (1 ) (1 ) (1 ) Actuarial (gain) loss 56 84 69 92 151 144 1 — 1 Net periodic defined benefit costs (credits) prior to settlements and termination benefits 33 63 81 (240 ) (169 ) (116 ) 10 4 8 Settlements 1 — 1 — — — — — — Termination benefits — — 1 — — — — — — Net periodic defined benefit costs (credits) $ 34 $ 63 $ 83 $ (240 ) $ (169 ) $ (116 ) $ 10 $ 4 $ 8 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement (1 ) — (1 ) — — — — — — Net (gain) loss (121 ) 157 27 723 201 346 (18 ) 8 (28 ) Prior service cost (credit) 2 1 (1 ) — 13 — — — 8 Amortization of: Prior service (cost) credit (8 ) (10 ) (10 ) (1 ) — — 1 1 1 Actuarial gain (loss) (56 ) (84 ) (69 ) (92 ) (151 ) (144 ) (1 ) — (1 ) Total recognized in OCI and regulatory assets/liabilities (a) (184 ) 64 (54 ) 630 63 202 (18 ) 9 (20 ) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (a) $ (150 ) $ 127 $ 29 $ 390 $ (106 ) $ 86 $ (8 ) $ 13 $ (12 ) (a) 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 2019 2018 2017 2019 2018 2017 OCI $ (194 ) $ 90 $ (53 ) $ (13 ) $ 20 $ (25 ) Regulatory assets/liabilities 10 (26 ) (1 ) (5 ) (11 ) 5 Total recognized in OCI and regulatory assets/liabilities $ (184 ) $ 64 $ (54 ) $ (18 ) $ 9 $ (20 )
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 2019 2018 2017 2019 2018 2017 2019 2018 2017 PPL $ 18 $ 40 $ 59 $ (287 ) $ (226 ) $ (151 ) $ 8 $ 2 $ 5 PPL Electric (a) (4 ) 4 12 4 (1 ) — LKE (b) 12 21 28 2 3 5 LG&E (b) 3 4 8 2 2 3 KU (a) (b) (1 ) 2 4 — 1 1 (a) PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 14 for additional information on costs allocated to 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, $2 million for LG&E and $1 million for KU were recorded as regulatory assets in 2019 , $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2018 and $4 million for LG&E and $2 million for KU were recorded as regulatory assets in 2017
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 2019 2018 2019 2018 2019 2018 PPL Discount rate 3.64 % 4.35 % 1.94 % 2.98 % 3.60 % 4.31 % Rate of compensation increase 3.79 % 3.79 % 3.25 % 3.50 % 3.76 % 3.76 % LKE Discount rate 3.62 % 4.35 % 3.59 % 4.32 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 3.60 % 4.33 % 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 2019 2018 2017 2019 2018 2017 2019 2018 2017 PPL Discount rate service cost 4.35 % 3.70 % 4.21 % 3.12 % 2.73 % 2.99 % 4.31 % 3.64 % 4.11 % Discount rate interest cost 4.35 % 3.70 % 4.21 % 2.62 % 2.31 % 2.41 % 4.31 % 3.64 % 4.11 % Rate of compensation increase 3.79 % 3.78 % 3.95 % 3.50 % 3.50 % 3.50 % 3.76 % 3.75 % 3.92 % Expected return on plan assets 7.25 % 7.25 % 7.00 % 7.21 % 7.23 % 7.22 % 6.46 % 6.40 % 6.21 % LKE Discount rate 4.35 % 3.69 % 4.19 % 4.32 % 3.65 % 4.12 % 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 % 7.00 % 7.00 % 7.15 % 6.82 % LG&E Discount rate 4.33 % 3.65 % 4.13 % Expected return on plan assets (a) 7.25 % 7.25 % 7.00 % (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: 2019 2018 2017 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.6 % 6.6 % 6.6 % – cost 6.6 % 6.6 % 7.0 % 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 2024 2023 2022 – cost 2023 2022 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 2019 2018 2019 2018 2019 2018 Change in Benefit Obligation Benefit Obligation, beginning of period $ 3,883 $ 4,288 $ 7,275 $ 8,219 $ 538 $ 589 Service cost 50 62 68 82 6 7 Interest cost 164 156 187 185 22 21 Participant contributions — — 12 13 14 13 Plan amendments 2 1 — 12 — — Actuarial (gain) loss 368 (352 ) 1,220 (406 ) 34 (34 ) Settlements (21 ) — — — — — Gross benefits paid (300 ) (272 ) (363 ) (381 ) (58 ) (58 ) Federal subsidy — — — — 1 — Currency conversion — — 116 (449 ) — — Benefit Obligation, end of period 4,146 3,883 8,515 7,275 557 538 Change in Plan Assets Plan assets at fair value, beginning of period 3,109 3,488 7,801 8,490 301 405 Actual return on plan assets 735 (260 ) 1,095 (30 ) 71 (20 ) Employer contributions 63 153 278 188 10 23 Participant contributions — — 12 13 10 11 Transfer out (a) — — — — — (65 ) Settlements (22 ) — — — — — Gross benefits paid (300 ) (272 ) (363 ) (381 ) (52 ) (53 ) Currency conversion — — 122 (479 ) — — Plan assets at fair value, end of period 3,585 3,109 8,945 7,801 340 301 Funded Status, end of period $ (561 ) $ (774 ) $ 430 $ 526 $ (217 ) $ (237 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 24 $ — $ 440 $ 535 $ 11 $ 2 Current liability (8 ) (13 ) (1 ) (1 ) (2 ) (3 ) Noncurrent liability (577 ) (761 ) (9 ) (8 ) (226 ) (236 ) Net amount recognized, end of period $ (561 ) $ (774 ) $ 430 $ 526 $ (217 ) $ (237 ) Pension Benefits U.S. U.K. Other Postretirement Benefits 2019 2018 2019 2018 2019 2018 Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 34 $ 40 $ 11 $ 12 $ 10 $ 10 Net actuarial (gain) loss 1,029 1,207 3,435 2,806 6 24 Total (b) $ 1,063 $ 1,247 $ 3,446 $ 2,818 $ 16 $ 34 Total accumulated benefit obligation for defined benefit pension plans $ 3,910 $ 3,668 $ 7,821 $ 6,689 (a) 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. (b) 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 2019 2018 2019 2018 AOCI $ 352 $ 370 $ 13 $ 21 Regulatory assets/liabilities 711 877 3 13 Total $ 1,063 $ 1,247 $ 16 $ 34
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 2019 2018 2019 2018 Projected benefit obligation $ 3,861 $ 3,883 $ 10 $ 9 Fair value of plan assets 3,275 3,109 — — U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2019 2018 2019 2018 Accumulated benefit obligation $ 3,624 $ 3,668 $ 10 $ 9 Fair value of plan assets 3,275 3,109 — —
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 2019 2019 (a) 2018 (a) Target Asset Allocation (a) Growth Portfolio 57 % 55 % 55 % Equity securities 34 % 30 % Debt securities (b) 14 % 15 % Alternative investments 9 % 10 % Immunizing Portfolio 42 % 43 % 43 % Debt securities (b) 35 % 39 % Derivatives 7 % 4 % Liquidity Portfolio 1 % 2 % 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, 2019 December 31, 2018 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 $ 182 $ 182 $ — $ — $ 220 $ 220 $ — $ — Equity securities: U.S. Equity 194 194 — — 159 159 — — U.S. Equity fund measured at NAV (a) 451 — — — 340 — — — International equity fund at NAV (a) 554 — — — 466 — — — Commingled debt measured at NAV (a) 621 — — — 543 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 310 309 1 — 212 212 — — Corporate 951 — 931 20 899 — 874 25 Other 14 — 14 — 17 — 17 — Alternative investments: Real estate measured at NAV (a) 88 — — — 90 — — — Private equity measured at NAV (a) 62 — — — 65 — — — Hedge funds measured at NAV (a) 194 — — — 175 — — — December 31, 2019 December 31, 2018 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 3 — 3 — 33 — 33 — Insurance contracts 4 — — 4 21 — — 21 PPL Services Corporation Master Trust assets, at fair value 3,628 $ 685 $ 949 $ 24 3,240 $ 591 $ 924 $ 46 Receivables and payables, net (b) 99 (2 ) 401(h) accounts restricted for other postretirement benefit obligations (142 ) (129 ) Total PPL Services Corporation Master Trust pension assets $ 3,585 $ 3,109 (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, 2019 is as follows: Corporate debt Insurance contracts 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2018 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 24 $ 37 Actual return on plan assets Relating to assets still held at the reporting date (2 ) 1 (1 ) Relating to assets sold during the period 3 — 3 Purchases, sales and settlements 11 (4 ) 7 Balance at end of period $ 25 $ 21 $ 46
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 Allocation 2019 2018 2019 Asset Class U.S. Equity securities 45 % 40 % 45 % Debt securities (a) 52 % 56 % 50 % Cash and cash equivalents (b) 3 % 4 % 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, 2019 December 31, 2018 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ — $ — $ 6 $ 6 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 89 — — — 69 — — — Commingled debt fund measured at NAV (a) 68 — — — 68 — — — Debt securities: Corporate bonds 35 — 35 — 28 — 28 — Total VEBA trust assets, at fair value 198 $ 6 $ 35 $ — 171 $ 6 $ 28 $ — Receivables and payables, net (b) — 1 401(h) account assets 142 129 Total other postretirement benefit plan assets $ 340 $ 301 (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 2019 2018 2019 Asset Class Cash and cash equivalents 2 % 2 % — % Equity securities U.K. — % — % 2 % European (excluding the U.K.) — % 1 % 1 % Asian-Pacific — % 1 % 1 % North American 1 % 1 % 1 % Emerging markets — % 1 % 1 % Global equities 19 % 19 % 9 % Global Tactical Asset Allocation 29 % 31 % 41 % Debt securities (a) 43 % 38 % 38 % Alternative investments 6 % 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, 2019 December 31, 2018 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 $ 154 $ 154 $ — $ — $ 147 $ 147 $ — $ — Equity securities measured at NAV (a) : U.K. companies 22 — — — 27 — — — European companies (excluding the U.K.) 54 — — — 76 — — — Asian-Pacific companies 35 — — — 49 — — — North American companies 74 — — — 105 — — — Emerging markets companies 32 — — — 44 — — — Global Equities 1,684 — — — 1,465 — — — Other 2,584 — — — 2,437 — — — Debt Securities: U.K. corporate bonds 5 — 5 — 4 — 4 — U.K. gilts 3,819 — 3,819 — 2,933 — 2,933 — Alternative investments: Real estate measured at NAV (a) 519 — — — 485 — — — Fair value - U.K. pension plans 8,982 $ 154 $ 3,824 $ — 7,772 $ 147 $ 2,937 $ — Receivables and payables, net (b) (37 ) 29 Total U.K. pension assets $ 8,945 $ 7,801 (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 Payment Expected Federal Subsidy 2020 $ 271 $ 50 $ 1 2021 267 48 1 2022 266 47 — 2023 264 46 — 2024 265 44 — 2025-2029 1,278 200 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 2020 $ 353 2021 351 2022 356 2023 359 2024 364 2025-2029 1,826
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: 2019 2018 2017 PPL $ 42 $ 40 $ 36 PPL Electric 6 6 6 LKE 21 20 18 LG&E 6 6 5 KU 5 5 4
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 liabilities at December 31 as follows: 2019 2018 Pension $ 179 $ 285 Other postretirement benefits 122 120
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 2019 2018 2017 2019 2018 2017 Net periodic defined benefit costs (credits): Service cost $ 22 $ 25 $ 24 $ 4 $ 4 $ 4 Interest cost 66 63 68 8 8 9 Expected return on plan assets (101 ) (102 ) (92 ) (8 ) (9 ) (7 ) Amortization of: Prior service cost 8 9 8 1 1 1 Actuarial (gain) loss (a) 22 35 31 (1 ) — — Net periodic defined benefit costs (b) $ 17 $ 30 $ 39 $ 4 $ 4 $ 7 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (gain) loss $ (37 ) $ 40 $ 30 $ (14 ) $ 1 $ (14 ) Prior service cost 2 — 7 — — 8 Amortization of: Prior service credit (8 ) (9 ) (8 ) (1 ) (1 ) (1 ) Actuarial gain (loss) (22 ) (35 ) (32 ) 1 — — Total recognized in OCI and regulatory assets/liabilities (65 ) (4 ) (3 ) (14 ) — (7 ) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ (48 ) $ 26 $ 36 $ (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 $5 million in 2019 and $11 million in 2018 and 2017 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019, $6 million in 2018 and $5 million in 2017 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 2019 2018 2017 2019 2018 2017 OCI $ 13 $ (25 ) $ 33 $ (7 ) $ 4 $ (2 ) Regulatory assets/liabilities (78 ) 21 (36 ) (7 ) (4 ) (5 ) Total recognized in OCI and regulatory assets/liabilities $ (65 ) $ (4 ) $ (3 ) $ (14 ) $ — $ (7 )
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 2019 2018 2019 2018 2019 2018 PPL Discount rate 3.64 % 4.35 % 1.94 % 2.98 % 3.60 % 4.31 % Rate of compensation increase 3.79 % 3.79 % 3.25 % 3.50 % 3.76 % 3.76 % LKE Discount rate 3.62 % 4.35 % 3.59 % 4.32 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 3.60 % 4.33 % 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 2019 2018 2017 2019 2018 2017 2019 2018 2017 PPL Discount rate service cost 4.35 % 3.70 % 4.21 % 3.12 % 2.73 % 2.99 % 4.31 % 3.64 % 4.11 % Discount rate interest cost 4.35 % 3.70 % 4.21 % 2.62 % 2.31 % 2.41 % 4.31 % 3.64 % 4.11 % Rate of compensation increase 3.79 % 3.78 % 3.95 % 3.50 % 3.50 % 3.50 % 3.76 % 3.75 % 3.92 % Expected return on plan assets 7.25 % 7.25 % 7.00 % 7.21 % 7.23 % 7.22 % 6.46 % 6.40 % 6.21 % LKE Discount rate 4.35 % 3.69 % 4.19 % 4.32 % 3.65 % 4.12 % 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 % 7.00 % 7.00 % 7.15 % 6.82 % LG&E Discount rate 4.33 % 3.65 % 4.13 % Expected return on plan assets (a) 7.25 % 7.25 % 7.00 % (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: 2019 2018 2017 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.6 % 6.6 % 6.6 % – cost 6.6 % 6.6 % 7.0 % 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 2024 2023 2022 – cost 2023 2022 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 2019 2018 2019 2018 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,580 $ 1,771 $ 205 $ 223 Service cost 22 25 4 4 Interest cost 66 63 8 8 Participant contributions — — 7 8 Plan amendments 2 — — — Actuarial (gain) loss (b) 166 (168 ) 5 (16 ) Settlements (16 ) — — — Gross benefits paid (a) (136 ) (111 ) (21 ) (22 ) Benefit Obligation, end of period 1,684 1,580 208 205 Change in Plan Assets Plan assets at fair value, beginning of period 1,294 1,402 117 116 Actual return on plan assets 304 (106 ) 27 (9 ) Employer contributions 24 109 11 24 Participant contributions — — 7 8 Settlements (16 ) — — — Gross benefits paid (136 ) (111 ) (21 ) (22 ) Plan assets at fair value, end of period 1,470 1,294 141 117 Funded Status, end of period $ (214 ) $ (286 ) $ (67 ) $ (88 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 24 $ — $ 11 $ 2 Current liability (5 ) (4 ) (2 ) (3 ) Noncurrent liability (233 ) (282 ) (76 ) (87 ) Net amount recognized, end of period $ (214 ) $ (286 ) $ (67 ) $ (88 ) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost $ 30 $ 35 $ 10 $ 12 Net actuarial (gain) loss 380 439 (37 ) (25 ) Total $ 410 $ 474 $ (27 ) $ (13 ) Total accumulated benefit obligation for defined benefit pension plans $ 1,561 $ 1,467 (a) Gross benefits paid by the plans include lump-sum cash payments made to participants during 2019 and 2018 of $74 million and $52 million . (b) The actuarial (gain) loss for all pension plans in 2019 and 2018 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 2019 2018 2019 2018 AOCI $ 132 $ 118 $ 4 $ 10 Regulatory assets/liabilities 278 356 (31 ) (23 ) Total $ 410 $ 474 $ (27 ) $ (13 )
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 2019 2018 Projected benefit obligation $ 1,398 $ 1,580 Fair value of plan assets 1,160 1,294 ABO in excess of plan assets 2019 2018 Accumulated benefit obligation $ 1,276 $ 1,467 Fair value of plan assets 1,160 1,294
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 2019 2019 (a) 2018 (a) Target Asset Allocation (a) Growth Portfolio 57 % 55 % 55 % Equity securities 34 % 30 % Debt securities (b) 14 % 15 % Alternative investments 9 % 10 % Immunizing Portfolio 42 % 43 % 43 % Debt securities (b) 35 % 39 % Derivatives 7 % 4 % Liquidity Portfolio 1 % 2 % 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, 2019 December 31, 2018 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 $ 182 $ 182 $ — $ — $ 220 $ 220 $ — $ — Equity securities: U.S. Equity 194 194 — — 159 159 — — U.S. Equity fund measured at NAV (a) 451 — — — 340 — — — International equity fund at NAV (a) 554 — — — 466 — — — Commingled debt measured at NAV (a) 621 — — — 543 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 310 309 1 — 212 212 — — Corporate 951 — 931 20 899 — 874 25 Other 14 — 14 — 17 — 17 — Alternative investments: Real estate measured at NAV (a) 88 — — — 90 — — — Private equity measured at NAV (a) 62 — — — 65 — — — Hedge funds measured at NAV (a) 194 — — — 175 — — — December 31, 2019 December 31, 2018 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 3 — 3 — 33 — 33 — Insurance contracts 4 — — 4 21 — — 21 PPL Services Corporation Master Trust assets, at fair value 3,628 $ 685 $ 949 $ 24 3,240 $ 591 $ 924 $ 46 Receivables and payables, net (b) 99 (2 ) 401(h) accounts restricted for other postretirement benefit obligations (142 ) (129 ) Total PPL Services Corporation Master Trust pension assets $ 3,585 $ 3,109 (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, 2019 is as follows: Corporate debt Insurance contracts 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2018 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 24 $ 37 Actual return on plan assets Relating to assets still held at the reporting date (2 ) 1 (1 ) Relating to assets sold during the period 3 — 3 Purchases, sales and settlements 11 (4 ) 7 Balance at end of period $ 25 $ 21 $ 46
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, 2019 December 31, 2018 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ — $ — $ 6 $ 6 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 89 — — — 69 — — — Commingled debt fund measured at NAV (a) 68 — — — 68 — — — Debt securities: Corporate bonds 35 — 35 — 28 — 28 — Total VEBA trust assets, at fair value 198 $ 6 $ 35 $ — 171 $ 6 $ 28 $ — Receivables and payables, net (b) — 1 401(h) account assets 142 129 Total other postretirement benefit plan assets $ 340 $ 301 (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 Payment Expected Federal Subsidy 2020 $ 114 $ 14 $ 1 2021 115 15 — 2022 115 15 — 2023 113 15 — 2024 115 15 — 2025-2029 545 72 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 2018 2017 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 $ 1 Interest cost 11 12 13 Expected return on plan assets (21 ) (22 ) (22 ) Amortization of: Prior service cost 5 5 5 Actuarial loss (a) 9 7 9 Net periodic defined benefit costs (b) $ 5 $ 3 $ 6 Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: Net (gain) loss $ (19 ) $ 22 $ (9 ) Prior service cost — — 7 Amortization of: Prior service credit (5 ) (5 ) (5 ) Actuarial gain (9 ) (7 ) (9 ) Total recognized in regulatory assets/liabilities (33 ) 10 (16 ) Total recognized in net periodic defined benefit costs and regulatory assets $ (28 ) $ 13 $ (10 ) (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 LG&E's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $3 million in 2019 , $2 million in 2018 and $7 million in 2017 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019, $6 million in 2018 and $5 million in 2017 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 14 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 2018 2017 2019 2018 2017 LG&E Non-Union Only $ — $ 2 $ 5 $ 2 $ 2 $ 3
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 2019 2018 2019 2018 2019 2018 PPL Discount rate 3.64 % 4.35 % 1.94 % 2.98 % 3.60 % 4.31 % Rate of compensation increase 3.79 % 3.79 % 3.25 % 3.50 % 3.76 % 3.76 % LKE Discount rate 3.62 % 4.35 % 3.59 % 4.32 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 3.60 % 4.33 % 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 2019 2018 2017 2019 2018 2017 2019 2018 2017 PPL Discount rate service cost 4.35 % 3.70 % 4.21 % 3.12 % 2.73 % 2.99 % 4.31 % 3.64 % 4.11 % Discount rate interest cost 4.35 % 3.70 % 4.21 % 2.62 % 2.31 % 2.41 % 4.31 % 3.64 % 4.11 % Rate of compensation increase 3.79 % 3.78 % 3.95 % 3.50 % 3.50 % 3.50 % 3.76 % 3.75 % 3.92 % Expected return on plan assets 7.25 % 7.25 % 7.00 % 7.21 % 7.23 % 7.22 % 6.46 % 6.40 % 6.21 % LKE Discount rate 4.35 % 3.69 % 4.19 % 4.32 % 3.65 % 4.12 % 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 % 7.00 % 7.00 % 7.15 % 6.82 % LG&E Discount rate 4.33 % 3.65 % 4.13 % Expected return on plan assets (a) 7.25 % 7.25 % 7.00 % (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 2018 Change in Benefit Obligation Benefit Obligation, beginning of period $ 285 $ 326 Service cost 1 1 Interest cost 11 12 Actuarial (gain) loss 25 (24 ) Gross benefits paid (a) (36 ) (30 ) Benefit Obligation, end of period 286 285 Change in Plan Assets Plan assets at fair value, beginning of period 281 325 Actual return on plan assets 64 (24 ) Employer contributions 1 10 Gross benefits paid (36 ) (30 ) Plan assets at fair value, end of period 310 281 Funded Status, end of period $ 24 $ (4 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset (liability) $ 24 $ (4 ) Net amount recognized, end of period $ 24 $ (4 ) Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost $ 17 $ 22 Net actuarial loss 79 107 Total $ 96 $ 129 Total accumulated benefit obligation for defined benefit pension plan $ 286 $ 285 (a) Gross benefits paid by the plan include lump-sum cash payments made to participants during 2019 and 2018 of $21 million and $16 million . Allocations to LG&E resulted in (assets)/liabilities at December 31 as follows: 2019 2018 Pension $ (7 ) $ 7 Other postretirement benefits 63 65
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 2019 2019 (a) 2018 (a) Target Asset Allocation (a) Growth Portfolio 57 % 55 % 55 % Equity securities 34 % 30 % Debt securities (b) 14 % 15 % Alternative investments 9 % 10 % Immunizing Portfolio 42 % 43 % 43 % Debt securities (b) 35 % 39 % Derivatives 7 % 4 % Liquidity Portfolio 1 % 2 % 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, 2019 December 31, 2018 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 $ 182 $ 182 $ — $ — $ 220 $ 220 $ — $ — Equity securities: U.S. Equity 194 194 — — 159 159 — — U.S. Equity fund measured at NAV (a) 451 — — — 340 — — — International equity fund at NAV (a) 554 — — — 466 — — — Commingled debt measured at NAV (a) 621 — — — 543 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 310 309 1 — 212 212 — — Corporate 951 — 931 20 899 — 874 25 Other 14 — 14 — 17 — 17 — Alternative investments: Real estate measured at NAV (a) 88 — — — 90 — — — Private equity measured at NAV (a) 62 — — — 65 — — — Hedge funds measured at NAV (a) 194 — — — 175 — — — December 31, 2019 December 31, 2018 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 3 — 3 — 33 — 33 — Insurance contracts 4 — — 4 21 — — 21 PPL Services Corporation Master Trust assets, at fair value 3,628 $ 685 $ 949 $ 24 3,240 $ 591 $ 924 $ 46 Receivables and payables, net (b) 99 (2 ) 401(h) accounts restricted for other postretirement benefit obligations (142 ) (129 ) Total PPL Services Corporation Master Trust pension assets $ 3,585 $ 3,109 (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, 2019 is as follows: Corporate debt Insurance contracts 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2018 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 24 $ 37 Actual return on plan assets Relating to assets still held at the reporting date (2 ) 1 (1 ) Relating to assets sold during the period 3 — 3 Purchases, sales and settlements 11 (4 ) 7 Balance at end of period $ 25 $ 21 $ 46
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, 2019 December 31, 2018 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ — $ — $ 6 $ 6 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 89 — — — 69 — — — Commingled debt fund measured at NAV (a) 68 — — — 68 — — — Debt securities: Corporate bonds 35 — 35 — 28 — 28 — Total VEBA trust assets, at fair value 198 $ 6 $ 35 $ — 171 $ 6 $ 28 $ — Receivables and payables, net (b) — 1 401(h) account assets 142 129 Total other postretirement benefit plan assets $ 340 $ 301
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. 2019 2018 Pension $ (31 ) $ 1 Other postretirement benefits 16 25

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2019
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 2 —
LG And E And KU Energy LLC [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 2 —
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 2 —
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2019 and 2018 , the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2018 Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 LG&E 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 — — December 31, 2018 E.W. Brown Units 6-7 38.00 % $ 41 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 17 — Trimble County Unit 1 75.00 % 427 77 — Trimble County Unit 2 14.25 % 226 39 152 Trimble County Units 5-6 29.00 % 32 11 — Trimble County Units 7-10 37.00 % 77 24 — Cane Run Unit 7 22.00 % 119 9 — E.W. Brown Solar Unit 39.00 % 10 1 — KU 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 — — December 31, 2018 E.W. Brown Units 6-7 62.00 % $ 66 $ 31 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 15 — Trimble County Unit 2 60.75 % 837 160 141 Trimble County Units 5-6 71.00 % 76 25 — Trimble County Units 7-10 63.00 % 129 41 — Cane Run Unit 7 78.00 % 428 36 — E.W. Brown Solar Unit 61.00 % 16 2 —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2019
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 Date Natural Gas Fuel 2022 Natural Gas Retail Supply 2021 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2020 $ 21 $ 10 $ 31 2021 21 10 31 2022 21 10 31 2023 21 10 31 2024 22 9 31 Thereafter 276 123 399 Total $ 382 $ 172 $ 554 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2019 2018 2017 LG&E $ 15 $ 14 $ 14 KU 7 6 6 Total $ 22 $ 20 $ 20
Guarantees	The table below details guarantees provided as of December 31, 2019 Exposure at Expiration Date PPL Indemnifications related to the WPD Midlands acquisition (a) WPD indemnifications for entities in liquidation and sales of assets $ 10 (b) 2021 WPD guarantee of pension and other obligations of unconsolidated entities 83 (c) PPL Electric Guarantee of inventory value 26 (d) 2020 LKE Indemnification of lease termination and other divestitures 200 (e) 2021 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (f) (a) Indemnifications related to certain liabilities, including a specific unresolved tax issue and those relating to properties and assets owned by the seller that were transferred to WPD Midlands in connection with the acquisition. A cross indemnity has been received from the seller on the tax issue. The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents. (b) 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. (c) 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, 2019 , 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. (d) A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm currently has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold. In December 2019, PPL Electric declared its intent to terminate the firm’s inventory procurement and fulfillment services effective March 2020. This guarantee has an estimated exposure of $ 26 million , which PPL Electric will assume subsequent to the termination date. In accordance with the agreement termination terms, PPL Electric has an obligation to purchase any remaining inventory within 90 days from termination date. (e) 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. (f) 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 $110 million at December 31, 2019 , consisting of LG&E's share of $76 million and KU's share of $34 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. In October 2019, the bankruptcy court issued an order confirming the sponsor's proposed reorganization plan. OVEC and other entities are challenging the contract rejection, the bankruptcy plan confirmation and potential FERC approval of the plan in various forums, and, in December 2019, an appellate court remanded the contract rejection issue for further proceedings. The plan's effective date remains subject to certain conditions precedent, including FERC regulatory approval, and relevant aspects of the contract rejection and the plan subject to on-going appellate, bankruptcy and regulatory proceedings. OVEC and certain of its sponsors, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs, establishing or continuing debt reserve accounts or other changes involving OVEC's existing short and long-term debt. The ultimate outcome of these matters, including the sponsor bankruptcy and related appellate or regulatory proceedings, OVEC structural or financial steps relating thereto and any other potential impact on LG&E's and KU's obligations relating to OVEC under the power purchase contract cannot be predicted.
LG And E And KU Energy LLC [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	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 2020 $ 21 $ 10 $ 31 2021 21 10 31 2022 21 10 31 2023 21 10 31 2024 22 9 31 Thereafter 276 123 399 Total $ 382 $ 172 $ 554 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2019 2018 2017 LG&E $ 15 $ 14 $ 14 KU 7 6 6 Total $ 22 $ 20 $ 20 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 Date Natural Gas Fuel 2022 Natural Gas Retail Supply 2021 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026
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 Date Natural Gas Fuel 2022 Natural Gas Retail Supply 2021 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2020 $ 21 $ 10 $ 31 2021 21 10 31 2022 21 10 31 2023 21 10 31 2024 22 9 31 Thereafter 276 123 399 Total $ 382 $ 172 $ 554 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2019 2018 2017 LG&E $ 15 $ 14 $ 14 KU 7 6 6 Total $ 22 $ 20 $ 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 Date Natural Gas Fuel 2022 Natural Gas Retail Supply 2021 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2020 $ 21 $ 10 $ 31 2021 21 10 31 2022 21 10 31 2023 21 10 31 2024 22 9 31 Thereafter 276 123 399 Total $ 382 $ 172 $ 554 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2019 2018 2017 LG&E $ 15 $ 14 $ 14 KU 7 6 6 Total $ 22 $ 20 $ 20

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2019
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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190
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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190
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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190
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. 2019 2018 2017 PPL Electric from PPL Services $ 59 $ 59 $ 182 LKE from PPL Services 28 26 20 PPL Electric from PPL EU Services 152 148 64 LG&E from LKS 160 151 169 KU from LKS 178 169 190

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2019
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2019 2018 2017 Other Income Economic foreign currency exchange contracts (Note 17) $ (14 ) $ 150 $ (261 ) Defined benefit plans - non-service credits (Note 11) 316 257 167 Interest income 16 6 2 AFUDC - equity component 23 21 16 Miscellaneous 7 6 17 Total Other Income 348 440 (59 ) Other Expense Charitable contributions 17 24 8 Miscellaneous 22 20 21 Total Other Expense 39 44 29 Other Income (Expense) - net $ 309 $ 396 $ (88 )
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: 2019 2018 2017 Other Income Defined benefit plans - non-service credits (Note 11) $ 4 $ 5 $ 1 Interest income 2 2 1 AFUDC - equity component 23 20 15 Total Other Income 29 27 17 Other Expense Charitable contributions 3 3 2 Miscellaneous 1 1 3 Total Other Expense 4 4 5 Other Income (Expense) - net $ 25 $ 23 $ 12

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 December 31, 2018 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 815 $ 815 $ — $ — $ 621 $ 621 $ — $ — Restricted cash and cash equivalents (a) 21 21 — — 22 22 — — Special use funds (a): Money market fund — — — — 59 59 — — Commingled debt fund measured at NAV (b) 29 — — — — — — — Commingled equity fund measured at NAV (b) 27 — — — — — — — Total special use funds 56 — — — 59 59 — — Price risk management assets (c): Foreign currency contracts 142 — 142 — 202 — 202 — Cross-currency swaps 154 — 154 — 135 — 135 — Total price risk management assets 296 — 296 — 337 — 337 — Total assets $ 1,188 $ 836 $ 296 $ — $ 1,039 $ 702 $ 337 $ — Liabilities Price risk management liabilities (c): Interest rate swaps $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — Foreign currency contracts 5 — 5 — 2 — 2 — Total price risk management liabilities $ 26 $ — $ 26 $ — $ 22 $ — $ 22 $ — PPL Electric Assets Cash and cash equivalents $ 262 $ 262 $ — $ — $ 267 $ 267 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 264 $ 264 $ — $ — $ 269 $ 269 $ — $ — LKE Assets Cash and cash equivalents $ 27 $ 27 $ — $ — $ 24 $ 24 $ — $ — Total assets $ 27 $ 27 $ — $ — $ 24 $ 24 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — Total price risk management liabilities $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — LG&E Assets Cash and cash equivalents $ 15 $ 15 $ — $ — $ 10 $ 10 $ — $ — Total assets $ 15 $ 15 $ — $ — $ 10 $ 10 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — Total price risk management liabilities $ 21 $ — $ 21 $ — $ 20 $ — $ 20 $ — December 31, 2019 December 31, 2018 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 KU Assets Cash and cash equivalents $ 12 $ 12 $ — $ — $ 14 $ 14 $ — $ — Total assets $ 12 $ 12 $ — $ — $ 14 $ 14 $ — $ — (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, 2019 December 31, 2018 Carrying Fair Value Carrying Fair Value PPL $ 21,893 $ 25,481 $ 20,599 $ 22,939 PPL Electric 3,985 4,589 3,694 3,901 LKE 6,002 6,766 5,502 5,768 LG&E 2,005 2,278 1,809 1,874 KU 2,623 3,003 2,321 2,451 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 December 31, 2018 Derivatives designated as hedging instruments Derivatives not designated as hedging instruments Derivatives designated as hedging instruments Derivatives not designated as hedging instruments Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ — $ — $ — $ 4 $ — $ — $ — $ 4 Cross-currency swaps (b) 5 — — — 6 — — — Foreign currency contracts — — 142 5 — — 103 2 Total current 5 — 142 9 6 — 103 6 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 17 — — — 16 Cross-currency swaps (b) 149 — — — 129 — — — Foreign currency contracts — — — — — — 99 — Total noncurrent 149 — — 17 129 — 99 16 Total derivatives $ 154 $ — $ 142 $ 26 $ 135 $ — $ 202 $ 22 (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	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 ) The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities: Derivative Relationships Derivative Gain (Loss) Recognized in OCI Location of Gain (Loss) Recognized in Income on Derivative Gain (Loss) Reclassified from AOCI into Income 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 2017 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (9 ) Cross-currency swaps (98 ) Other Income (Expense) - net (82 ) Total $ (98 ) $ (91 ) Net Investment Hedges: Foreign currency contracts $ 1 Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized in Income on Derivative 2019 2018 2017 Foreign currency contracts Other Income (Expense) - net $ (14 ) $ 150 $ (261 ) Interest rate swaps Interest Expense (5 ) (5 ) (6 ) Total $ (19 ) $ 145 $ (267 ) Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets 2019 2018 2017 Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 6 $ 5
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 Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20
Credit Risk-Related Contingent Features	At December 31, 2019 , 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 LKE LG&E Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 3 $ 3 $ 3 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) 3 3 3 (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, 2019 December 31, 2018 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 4 $ — $ 4 Total current — 4 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 17 — 16 Total noncurrent — 17 — 16 Total derivatives $ — $ 21 $ — $ 20
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) 2019 2018 2017 Interest rate swaps Interest Expense $ (5 ) $ (5 ) $ (6 ) Derivative Instruments Location of Gain (Loss) 2019 2018 2017 Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 6 $ 5
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 Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20
Credit Risk-Related Contingent Features	At December 31, 2019 , 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 LKE LG&E Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 3 $ 3 $ 3 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) 3 3 3 (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, 2019 December 31, 2018 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 4 $ — $ 4 Total current — 4 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 17 — 16 Total noncurrent — 17 — 16 Total derivatives $ — $ 21 $ — $ 20
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) 2019 2018 2017 Interest rate swaps Interest Expense $ (5 ) $ (5 ) $ (6 ) Derivative Instruments Location of Gain (Loss) 2019 2018 2017 Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 6 $ 5
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 Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20
Credit Risk-Related Contingent Features	At December 31, 2019 , 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 LKE LG&E Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 3 $ 3 $ 3 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) 3 3 3 (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 Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net December 31, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Goodwill and Other Intangible Assets [Line Items]
Goodwill Rollforward	The changes in the carrying amount of goodwill by segment were: U.K. Regulated Kentucky Regulated Corporate and Other Total 2019 2018 2019 2018 2019 2018 2019 2018 Balance at beginning of period (a) $ 2,447 $ 2,596 $ 662 $ 662 $ 53 $ — $ 3,162 $ 3,258 Effect of foreign currency exchange rates 34 (149 ) — — — — 34 (149 ) Goodwill recognized during the period (b) — — — — — 53 — 53 Other 2 — — — — — 2 — Balance at end of period (a) $ 2,483 $ 2,447 $ 662 $ 662 $ 53 $ 53 $ 3,198 $ 3,162 (a) There were no accumulated impairment losses related to goodwill. (b) Recognized as a result of the acquisition of Safari Energy.
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Contracts (a) $ 136 $ 84 $ 137 $ 75 Land rights and easements 440 135 418 128 Licenses and other 22 3 21 1 Total subject to amortization 598 222 576 204 Not subject to amortization due to indefinite life: Land rights and easements 361 — 339 — Other 6 — 6 — Total not subject to amortization due to indefinite life 367 — 345 — Total $ 965 $ 222 $ 921 $ 204 (a) Gross carrying amount in 2019 and 2018 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: 2019 2018 2017 Intangible assets with no regulatory offset $ 9 $ 7 $ 6 Intangible assets with regulatory offset 9 8 9 Total $ 18 $ 15 $ 15
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 Intangible assets with no regulatory offset $ 9 $ 9 $ 9 $ 9 $ 9 Intangible assets with regulatory offset 8 8 8 8 8 Total $ 17 $ 17 $ 17 $ 17 $ 17
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, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 370 $ 125 $ 363 $ 121 Licenses and other 3 1 2 1 Total subject to amortization 373 126 365 122 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 390 $ 126 $ 382 $ 122
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, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 22 $ 4 $ 21 $ 3 OVEC power purchase agreement (a) 125 74 126 66 Total subject to amortization $ 147 $ 78 $ 147 $ 69 (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: 2019 2018 2017 Intangible assets with regulatory offset $ 9 $ 8 $ 9
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 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, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 51 87 46 Total subject to amortization $ 93 $ 52 $ 94 $ 47 (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: 2019 2018 2017 Intangible assets with regulatory offset $ 6 $ 6 $ 6
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 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, 2019 December 31, 2018 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 15 $ 3 $ 14 $ 2 OVEC power purchase agreement (a) 39 23 39 20 Total subject to amortization $ 54 $ 26 $ 53 $ 22 (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: 2019 2018 2017 Intangible assets with regulatory offset $ 3 $ 2 $ 3
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2020 2021 2022 2023 2024 Intangible assets with regulatory offset $ 2 $ 2 $ 2 $ 2 $ 2

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2019
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 2019 2018 2019 2018 2019 2018 2019 2018 ARO at beginning of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235 Accretion 19 20 17 18 6 6 11 12 Obligations incurred — 8 — 8 — — — 8 Changes in estimated timing or cost 12 (3 ) (2 ) (14 ) (2 ) (2 ) — (12 ) Effect of foreign currency exchange rates — (3 ) — — — — — — Obligations settled (96 ) (72 ) (96 ) (72 ) (34 ) (22 ) (62 ) (50 ) ARO at end of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193
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 2019 2018 2019 2018 2019 2018 2019 2018 ARO at beginning of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235 Accretion 19 20 17 18 6 6 11 12 Obligations incurred — 8 — 8 — — — 8 Changes in estimated timing or cost 12 (3 ) (2 ) (14 ) (2 ) (2 ) — (12 ) Effect of foreign currency exchange rates — (3 ) — — — — — — Obligations settled (96 ) (72 ) (96 ) (72 ) (34 ) (22 ) (62 ) (50 ) ARO at end of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193
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 2019 2018 2019 2018 2019 2018 2019 2018 ARO at beginning of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235 Accretion 19 20 17 18 6 6 11 12 Obligations incurred — 8 — 8 — — — 8 Changes in estimated timing or cost 12 (3 ) (2 ) (14 ) (2 ) (2 ) — (12 ) Effect of foreign currency exchange rates — (3 ) — — — — — — Obligations settled (96 ) (72 ) (96 ) (72 ) (34 ) (22 ) (62 ) (50 ) ARO at end of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193
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 2019 2018 2019 2018 2019 2018 2019 2018 ARO at beginning of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235 Accretion 19 20 17 18 6 6 11 12 Obligations incurred — 8 — 8 — — — 8 Changes in estimated timing or cost 12 (3 ) (2 ) (14 ) (2 ) (2 ) — (12 ) Effect of foreign currency exchange rates — (3 ) — — — — — — Obligations settled (96 ) (72 ) (96 ) (72 ) (34 ) (22 ) (62 ) (50 ) ARO at end of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the year 538 (79 ) — — (308 ) 151 Reclassifications from AOCI — 73 1 1 130 205 Net OCI during the year 538 (6 ) 1 1 (178 ) 356 December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Defined benefit plans Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total 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 (Note 1) — (1 ) — (3 ) (47 ) (51 ) 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 ) LKE December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the year — (2 ) (23 ) (25 ) Reclassifications from AOCI 1 1 5 7 Net OCI during the year 1 (1 ) (18 ) (18 ) 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 )
Reclassification out of Other Comprehensive Income (Loss)	PPL Details about AOCI 2019 2018 2017 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (9 ) $ (8 ) $ (9 ) Interest Expense Cross-currency swaps (9 ) 42 (82 ) Other Income (Expense) - net — 1 — Interest Expense Total Pre-tax (18 ) 35 (91 ) Income Taxes 5 (6 ) 18 Total After-tax (13 ) 29 (73 ) Equity Investees' AOCI — — (1 ) Other Income (Expense) - net Total Pre-tax — — (1 ) Income Taxes — — — Total After-tax — — (1 ) Defined benefit plans Prior service costs (3 ) (2 ) (2 ) Net actuarial loss (109 ) (178 ) (167 ) Total Pre-tax (112 ) (180 ) (169 ) Income Taxes 23 36 38 Total After-tax (89 ) (144 ) (131 ) Total reclassifications during the year $ (102 ) $ (115 ) $ (205 ) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2019 , 2018 and 2017
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 Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the year 538 (79 ) — — (308 ) 151 Reclassifications from AOCI — 73 1 1 130 205 Net OCI during the year 538 (6 ) 1 1 (178 ) 356 December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Defined benefit plans Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Equity investees' AOCI Prior service costs Actuarial gain (loss) Total 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 (Note 1) — (1 ) — (3 ) (47 ) (51 ) 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 ) LKE December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the year — (2 ) (23 ) (25 ) Reclassifications from AOCI 1 1 5 7 Net OCI during the year 1 (1 ) (18 ) (18 ) 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 )

Quarterly Financial Information

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL AND DIVIDEND DATA (Unaudited) PPL Corporation and Subsidiaries (Millions of Dollars, except per share data) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2019 Operating revenues $ 2,079 $ 1,803 $ 1,933 $ 1,954 Operating income 781 640 726 693 Net income 466 441 475 364 Net income available to PPL common shareowners: (b) Basic EPS 0.65 0.61 0.66 0.49 Diluted EPS 0.64 0.60 0.65 0.48 2018 Operating revenues $ 2,126 $ 1,848 $ 1,872 $ 1,939 Operating income 851 658 686 657 Net income 452 515 445 415 Net income available to PPL common shareowners: (b) Basic EPS 0.65 0.74 0.63 0.57 Diluted EPS 0.65 0.73 0.62 0.57 (a) Quarterly results can vary depending on, among other things, weather. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations. (b) The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL DATA (Unaudited) PPL Electric Utilities Corporation and Subsidiaries (Millions of Dollars) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2019 Operating revenues $ 645 $ 521 $ 590 $ 602 Operating income 198 161 193 193 Net income 121 94 118 124 2018 Operating revenues $ 639 $ 517 $ 548 $ 573 Operating income 228 133 178 155 Net income 148 75 111 96 (a) PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)Integer	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Utility Revenue (Details) [Abstract]
Operating Revenues	$ 1,954	$ 1,933	$ 1,803	$ 2,079	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 7,769	$ 7,785	$ 7,447
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	815				621				815	621
Restricted cash - current	3				3				3	3
Restricted Cash - noncurrent	18				19				18	19
Total Cash, Cash Equivalents and Restricted Cash	836				643				836	643	511	$ 372
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period									$ 10	15	$ 11
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	332				303				$ 332	303
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	106				98				106	98
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	35				41				35	41
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	191				164				$ 191	$ 164
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									2.84%	2.77%	2.65%
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				56				51	$ 56	$ 51	$ 54
Additions charged to income									37	41	28
Additions charged to other accounts									3	3	(1)
Deductions									38	39	30
Balance at end of period	58				56				$ 58	56	51
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
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	602	$ 590	$ 521	645	573	$ 548	$ 517	639	$ 2,358	2,277	2,195
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	262				267				262	267
Restricted cash - current	2				2				2	2
Restricted Cash - noncurrent	0				0				0	0
Total Cash, Cash Equivalents and Restricted Cash	264				269				$ 264	269	$ 51	15
Property, Plant and Equipment (Numeric) [Abstract]
Regulatory Asset Amortization Period									5 years
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)	3				19				$ 3	$ 19
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.05%	3.01%	2.86%
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				27				24	$ 27	$ 24	$ 28
Additions charged to income									26	29	18
Additions charged to other accounts									0	0	0
Deductions									25	26	22
Balance at end of period	28				27				28	27	24
LG And E And KU Energy LLC [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues									3,206	3,214	3,156
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	27				24				$ 27	24	$ 30	13
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)	(8)				(16)				$ (8)	(16)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	250				248				250	248
LG And E And KU Energy LLC [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	106				98				106	98
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	35				41				35	41
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	109				109				$ 109	$ 109
LG And E And KU Energy LLC [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.96%	3.69%	3.64%
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				27				25	$ 27	$ 25	$ 24
Additions charged to income									8	10	8
Additions charged to other accounts									3	3	(1)
Deductions									10	11	6
Balance at end of period	28				27				28	27	25
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues									1,500	1,496	1,453
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	15				10				$ 15	10	$ 15	5
Discount Rate Change For United Kingdom Pension Plans Numeric [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization									30.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis									10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis									30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized									50.00%
Intercompany tax receivables (payables)	(4)				0				$ (4)	0
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	122				127				122	127
Louisville Gas And Electric Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	43				42				43	42
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	35				41				35	41
Louisville Gas And Electric Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	44				44				$ 44	$ 44
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.87%	3.63%	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	$ 1	$ 2
Additions charged to income									2	4	2
Additions charged to other accounts									2	1	(1)
Deductions									4	5	2
Balance at end of period	1				1				1	1	1
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues									1,740	1,760	1,744
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	12				14				$ 12	14	$ 15	$ 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)	(6)				(5)				$ (6)	(5)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	128				121				128	121
Kentucky Utilities Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	63				56				63	56
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				0	0
Kentucky Utilities Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	65				65				$ 65	$ 65
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									4.02%	3.74%	3.66%
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				$ 2				$ 1	$ 2	$ 1	$ 2
Additions charged to income									4	5	4
Additions charged to other accounts									1	2	(1)
Deductions									6	6	4
Balance at end of period	$ 1				$ 2				$ 1	$ 2	$ 1

New Accounting Guidance Adopted

New Accounting Guidance Adopted (Details) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019
Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 96	$ 81
Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	26	23
Other Deferred Credits And Noncurrent Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Noncurrent	78	67
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	47	56
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	18
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	39	46
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	18	23
Louisville Gas And Electric Co [Member] | Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	6	9
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	18
Kentucky Utilities Co [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	28	31
Kentucky Utilities Co [Member] | Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	10	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	$ 23	$ 26

Segment and Related Informati_3

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) $ in Millions		3 Months Ended								12 Months Ended
		Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)Integer		Dec. 31, 2018USD ($)		Dec. 31, 2017USD ($)
Income Statement Data
Operating Revenues from external customers		$ 1,954	$ 1,933	$ 1,803	$ 2,079	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 7,769		$ 7,785		$ 7,447
Depreciation										1,199		1,094		1,008
Amortization										81		78		97
Unrealized (gains) losses on derivatives and other hedging activities										73		(186)		178
Interest Expense										994		963		901
Income Before Income Taxes										2,155		2,285		1,912
Income Taxes										409		458		784
Deferred income taxes and investment tax credits										309		355		707
Net income		364	475	441	466	415	445	515	452	1,746		1,827		1,128
Cash Flow Data
Expenditures for long-lived assets										3,107		3,268		3,171
Balance Sheet Data
Total Assets		45,680				43,396				$ 45,680		43,396
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer										3
U.K. Regulated [Member]
Income Statement Data
Operating Revenues from external customers										$ 2,167		2,268		2,091
Depreciation										250		247		230
Amortization										25		34		34
Unrealized (gains) losses on derivatives and other hedging activities										62		(190)		166
Interest Expense										405		413		397
Income Before Income Taxes										1,169		1,339		804
Income Taxes										192		225		152
Deferred income taxes and investment tax credits										140		118		66
Net income										977		1,114		652
Cash Flow Data
Expenditures for long-lived assets										857		954		1,015
Balance Sheet Data
Total Assets		17,622				16,700				17,622		16,700
Segment Information (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		13,200				12,400				13,200		12,400
Kentucky Regulated [Member]
Income Statement Data
Operating Revenues from external customers										3,206		3,214		3,156
Depreciation										547		475		439
Amortization										27		18		24
Unrealized (gains) losses on derivatives and other hedging activities										6		6		6
Interest Expense										298		274		261
Income Before Income Taxes										530		531		645
Income Taxes										94		120		359
Deferred income taxes and investment tax credits										82		94		294
Net income										436		411		286
Cash Flow Data
Expenditures for long-lived assets										1,097		1,117		892
Balance Sheet Data
Total Assets		15,597				15,078				15,597		15,078
Pennsylvania Regulated [Member]
Income Statement Data
Operating Revenues from external customers										2,358		2,277		2,195
Depreciation										386		352		309
Amortization										24		22		33
Interest Expense										169		159		142
Income Before Income Taxes										607		567		575
Income Taxes										149		136		216
Deferred income taxes and investment tax credits										90		125		257
Net income										458		431		359
Cash Flow Data
Expenditures for long-lived assets										1,121		1,196		1,254
Balance Sheet Data
Total Assets		11,918				11,257				11,918		11,257
Corporate And Other [Member]
Income Statement Data
Operating Revenues from external customers										38		26		5
Depreciation										16		20		30
Amortization										5		4		6
Unrealized (gains) losses on derivatives and other hedging activities										5		(2)		6
Interest Expense										122		117		101
Income Before Income Taxes										(151)		(152)		(112)
Income Taxes										(26)		(23)		57
Deferred income taxes and investment tax credits										(3)		18		90
Net income										(125)		(129)		(169)
Cash Flow Data
Expenditures for long-lived assets										32		1		10
Balance Sheet Data
Total Assets		543				361				543		361
PPL Electric Utilities Corp [Member]
Income Statement Data
Operating Revenues from external customers		602	590	521	645	573	548	517	639	2,358		2,277		2,195
Depreciation										386		352		309
Amortization										24		22		33
Interest Expense										170		159		142
Income Before Income Taxes										606		566		575
Income Taxes										149		136		213
Deferred income taxes and investment tax credits										90		125		258
Net income		124	$ 118	$ 94	$ 121	96	$ 111	$ 75	$ 148	457	[1]	430	[1]	362	[1]
Balance Sheet Data
Total Assets		11,901				11,243				$ 11,901		11,243
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										$ 3,206		3,214		3,156
Depreciation										547		475		439
Amortization										27		18		24
Interest Expense										226		206		197
Income Before Income Taxes										571		574		691
Income Taxes										103		129		375
Deferred income taxes and investment tax credits										82		94		294
Net income										468		445		316
Balance Sheet Data
Total Assets		15,931				15,412				$ 15,931		15,412
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										$ 1,500		1,496		1,453
Depreciation										231		195		183
Amortization										15		14		14
Interest Expense										87		76		71
Income Before Income Taxes										295		297		344
Income Taxes										63		64		131
Deferred income taxes and investment tax credits										56		60		126
Net income	[2]									232		233		213
Balance Sheet Data
Total Assets		7,133				6,883				$ 7,133		6,883
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										$ 1,740		1,760		1,744
Depreciation										315		279		255
Amortization										10		3		9
Interest Expense										109		100		96
Income Before Income Taxes										372		362		418
Income Taxes										79		76		159
Deferred income taxes and investment tax credits										39		48		152
Net income	[3]									293		286		$ 259
Balance Sheet Data
Total Assets		$ 8,825				$ 8,540				$ 8,825		$ 8,540
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 approximates comprehensive income.

Segment and Related Informati_4

Segment and Related Information (Geographic Data) (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers	$ 1,954	$ 1,933	$ 1,803	$ 2,079	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 7,769	$ 7,785	$ 7,447
Long-lived assets	37,225				35,175				37,225	35,175
U.S. [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers									5,602	5,517	5,356
Long-lived assets	23,607				22,384				23,607	22,384
U.K. [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	$ 13,618				$ 12,791				13,618	12,791
U.K. Regulated [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers									$ 2,167	$ 2,268	$ 2,091

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)Days	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2020USD ($)
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 1,954	$ 1,933	$ 1,803	$ 2,079	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 7,769	$ 7,785	$ 7,447
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									(30)	32
Other Revenue									(38)	(38)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									7,701	7,779
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)									27	34
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	44				42				44	42	29
Contract with Customer, Liability, Revenue Recognized									32	21
Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									2,032	2,127
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									2,610	2,704
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,257	1,233
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									621	624
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									495	489
Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									43	118
Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									49	79
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									594	405
Pennsylvania Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 2,358	2,277	2,195
Number Of Days Due From Invoice Date | Days									21
U.K. Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 2,167	2,268	2,091
Number Of Days Due From Invoice Date | Days									14
Kentucky Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 3,206	3,214	3,156
Number Of Days Due From Invoice Date | Days									22
Corporate Segment [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 38	26	5
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
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-12-31 | Corporate Segment [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	36								$ 36
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-12-31 | Corporate Segment [Member] | Forecast [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount												$ 32
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period												12 months
PPL Electric Utilities Corp [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	602	$ 590	$ 521	$ 645	573	$ 548	$ 517	$ 639	$ 2,358	2,277	2,195
Number Of Days Due From Invoice Date | Days									21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									$ (6)	(6)
Other Revenue									(10)	(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									2,342	2,259
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)									21	24
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	21				23				21	23	19
Contract with Customer, Liability, Revenue Recognized									11	8
PPL Electric Utilities Corp [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,288	1,379
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									349	368
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									59	54
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									52	53
PPL Electric Utilities Corp [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
PPL Electric Utilities Corp [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
PPL Electric Utilities Corp [Member] | Distribution [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,700	1,900
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									594	405
LG And E And KU Energy LLC [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									3,206	3,214	3,156
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									(24)	38
Other Revenue									(21)	(17)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									3,161	3,235
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)									6	9
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	9				9				9	9	8
Contract with Customer, Liability, Revenue Recognized									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
LG And E And KU Energy LLC [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,322	1,325
LG And E And KU Energy LLC [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									908	865
LG And E And KU Energy LLC [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									562	570
LG And E And KU Energy LLC [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									277	278
LG And E And KU Energy LLC [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									43	118
LG And E And KU Energy LLC [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									49	79
LG And E And KU Energy LLC [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									$ 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									$ 1,500	1,496	1,453
Number Of Days Due From Invoice Date | Days									22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									$ (10)	12
Other Revenue									(9)	(5)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,481	1,503
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)									2	4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	5				5				5	5	4
Contract with Customer, Liability, Revenue Recognized									5	4
Louisville Gas And Electric Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									668	666
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									466	455
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									180	180
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									121	129
Louisville Gas And Electric Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
Louisville Gas And Electric Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									46	73
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
Kentucky Utilities Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 1,740	1,760	1,744
Number Of Days Due From Invoice Date | Days									22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									$ (14)	26
Other Revenue									(12)	(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,714	1,774
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)									4	5
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	$ 4				$ 4				4	4	$ 4
Contract with Customer, Liability, Revenue Recognized									4	4
Kentucky Utilities Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0	0
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									654	659
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									442	410
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									382	390
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									156	149
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									43	118
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									37	48
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									$ 0	$ 0

Preferred Securities (Details)

Preferred Securities (Details) - $ / shares	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	10,000,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
PPL Electric Utilities Corp [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	20,629,936
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Louisville Gas And Electric Co [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	1,720,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Par value of stock	$ 25
Louisville Gas And Electric Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	6,750,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Kentucky Utilities Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	5,300,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Kentucky Utilities Co [Member] | Preference Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	2,000,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income (Numerator)
Net income	$ 364	$ 475	$ 441	$ 466	$ 415	$ 445	$ 515	$ 452	$ 1,746	$ 1,827	$ 1,128
Less amounts allocated to participating securities									1	2	2
Net income available to PPL common shareowners - Basic									1,745	1,825	1,126
Net income available to PPL common shareowners - Diluted									$ 1,745	$ 1,825	$ 1,126
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)									728,512	704,439	685,240
Add incremental non-participating securities:
Share-based payment awards (in shares)									1,101	445	2,094
Forward sales agreements									7,141	3,735	0
Weighted-average shares - Diluted EPS (in shares)									736,754	708,619	687,334
Basic EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 0.49	$ 0.66	$ 0.61	$ 0.65	$ 0.57	$ 0.63	$ 0.74	$ 0.65	$ 2.39	$ 2.59	$ 1.64
Diluted EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 0.48	$ 0.65	$ 0.60	$ 0.64	$ 0.57	$ 0.62	$ 0.73	$ 0.65	$ 2.37	$ 2.58	$ 1.64
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock issued under DRIP (in shares)									1,725
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)									1,936
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS									0	172	696
Performance Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS									5	0	0
Restricted Stock Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS									3	11	0

Income and Other Taxes (Tax Ref

Income and Other Taxes (Tax Reform) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 409	$ 458	$ 784
Net Increase in Regulatory Liability	88	(13)	12
Deferred Tax Liabilities, Net	3,064	2,768
Tax Cuts And Jobs Act [Member]
Tax Reform [Line Items]
Taxable Deemed Dividend			462
Income Tax Expense (Benefit)			321
Net Increase in Regulatory Liability	2,185		2,185
Deferred Tax Liabilities, Net			101
Tax Cuts And Jobs Act [Member] | Non-Regulated Deferred Tax Assets And Liabilities [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			220
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)	149	136	213
Net Increase in Regulatory Liability	43	19	5
Deferred Tax Liabilities, Net	1,447	1,320
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(13)
Net Increase in Regulatory Liability	1,019		1,019
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Non-Regulated Deferred Tax Assets And Liabilities [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 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)	103	129	375
Net Increase in Regulatory Liability	45	(32)	7
Deferred Tax Liabilities, Net	1,069	956
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			112
Net Increase in Regulatory Liability	1,166		1,166
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Non-Regulated Deferred Tax Assets And Liabilities [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			112
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)	63	64	131
Net Increase in Regulatory Liability	19	(5)	5
Deferred Tax Liabilities, Net	697	628
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			0
Net Increase in Regulatory Liability	532		532
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Non-Regulated Deferred Tax Assets And Liabilities [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			0
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)	79	76	159
Net Increase in Regulatory Liability	26	(27)	2
Deferred Tax Liabilities, Net	792	735
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			0
Net Increase in Regulatory Liability	$ 634		634
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Non-Regulated Deferred Tax Assets And Liabilities [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			$ 0
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, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Before Income Taxes (Details) [Abstract]
Domestic income	$ 964	$ 1,127	$ 874
Foreign income	1,191	1,158	1,038
Income Before Income Taxes	2,155	2,285	1,912
Deferred Tax Assets
Deferred investment tax credits	31	31
Regulatory liabilities	75	87
Income taxes due to customer	462	479
Accrued pension and postretirement costs	211	277
Federal loss carryforwards	324	325
State loss carryforwards	432	419
Federal and state tax credit carryforwards	402	392
Foreign capital loss carryforwards	320	313
Foreign - other	8	10
Contributions in aid of construction	112	139
Domestic - other	99	88
Valuation allowances	(834)	(808)
Total deferred tax assets	1,642	1,752
Deferred Tax Liabilities
Domestic plant - net	3,546	3,359
Regulatory assets	262	314
Foreign plant - net	765	724
Foreign - pensions	72	83
Domestic - other	61	40
Total deferred tax liabilities	4,706	4,520
Net deferred tax liability	3,064	2,768
Loss carryforwards
Federal loss carryforwards	324	325
State loss carryforwards	432	419
Foreign capital loss carryforwards	320	313
Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	315
Loss carryforwards
Net operating losses	1,499
Charitable contributions	42
Federal loss carryforwards	315
Charitable contribution carryforwards	9
Other Federal Loss Carryforwards	1
Loss carryforward valuation allowance on net operating losses	0
Charitable Contributions Loss Carryforwards valuation allowance	0
Other Loss Carryforward	7
Loss Carryforward Valuation Allowance Other	0
State [Member]
Deferred Tax Assets
State loss carryforwards	432
Loss carryforwards
Net operating losses	5,879
Charitable contributions	1
State loss carryforwards	432
Charitable contribution carryforwards	0
Loss carryforward valuation allowance on net operating losses	(393)
Charitable Contributions Loss Carryforwards valuation allowance	0
Foreign Tax Authority [Member]
Deferred Tax Assets
Foreign capital loss carryforwards	320
Foreign loss carryforwards	0
Loss carryforwards
Net operating losses	3
Capital losses	1,880
Foreign loss carryforwards	0
Foreign capital loss carryforwards	320
Loss carryforward valuation allowance on net operating losses	0
Loss carryforward valuation allowance on capital losses	(320)
Tax Cuts And Jobs Act [Member]
Deferred Tax Liabilities
Net deferred tax liability			101
Other Noncurrent Assets [Member]
Deferred Tax Liabilities
Deferred Tax Assets, State Taxes	24	28
PPL Electric Utilities Corp [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	606	566	575
Deferred Tax Assets
Regulatory liabilities	31	35
Income taxes due to customer	170	181
Accrued pension and postretirement costs	81	110
Federal loss carryforwards	78	79
State loss carryforwards	6	14
Contributions in aid of construction	88	118
Domestic - other	23	25
Total deferred tax assets	477	562
Deferred Tax Liabilities
Domestic plant - net	1,761	1,681
Regulatory assets	139	176
Domestic - other	24	25
Total deferred tax liabilities	1,924	1,882
Net deferred tax liability	1,447	1,320
Loss carryforwards
Federal loss carryforwards	78	79
State loss carryforwards	6	14
PPL Electric Utilities Corp [Member] | Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	76
Loss carryforwards
Net operating losses	363
Charitable contributions	9
Federal loss carryforwards	76
Charitable contribution carryforwards	2
PPL Electric Utilities Corp [Member] | State [Member]
Deferred Tax Assets
State loss carryforwards	6
Loss carryforwards
Net operating losses	81
State loss carryforwards	6
LG And E And KU Energy LLC [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	571	574	691
Deferred Tax Assets
Deferred investment tax credits	31	32
Regulatory liabilities	44	52
Income taxes due to customer	292	299
Deferred Tax Assets, Lease Liabilities	14	0
Accrued pension and postretirement costs	71	92
State tax credit carryforwards	19	1
Federal loss carryforwards	140	142
State loss carryforwards	31	33
Federal and state tax credit carryforwards	162	169
Contributions in aid of construction	23	21
Domestic - other	28	28
Valuation allowances	(6)	(8)
Total deferred tax assets	849	861
Deferred Tax Liabilities
Domestic plant - net	1,778	1,671
Regulatory assets	122	138
Lease right-of-use assets	12	0
Domestic - other	6	8
Total deferred tax liabilities	1,918	1,817
Net deferred tax liability	1,069	956
Loss carryforwards
Federal loss carryforwards	140	142
State loss carryforwards	31	33
LG And E And KU Energy LLC [Member] | Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	140
Loss carryforwards
Net operating losses	668
Charitable contributions	23
Federal loss carryforwards	140
Charitable contribution carryforwards	5
Loss carryforward valuation allowance on net operating losses	0
Charitable Contributions Loss Carryforwards valuation allowance	0
LG And E And KU Energy LLC [Member] | State [Member]
Deferred Tax Assets
State loss carryforwards	31
Loss carryforwards
Net operating losses	797
State loss carryforwards	31
Loss carryforward valuation allowance on net operating losses	0
Louisville Gas And Electric Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	295	297	344
Deferred Tax Assets
Deferred investment tax credits	8	9
Regulatory liabilities	19	24
Income taxes due to customer	136	139
Deferred Tax Assets, Lease Liabilities	5	0
Accrued pension and postretirement costs	6	16
State tax credit carryforwards	14	0
Contributions in aid of construction	15	14
Domestic - other	10	15
Valuation allowances	(14)	0
Total deferred tax assets	199	217
Deferred Tax Liabilities
Domestic plant - net	811	751
Regulatory assets	77	88
Lease right-of-use assets	4	0
Domestic - other	4	6
Total deferred tax liabilities	896	845
Net deferred tax liability	697	628
Kentucky Utilities Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	372	362	$ 418
Deferred Tax Assets
Deferred investment tax credits	23	23
Regulatory liabilities	25	28
Income taxes due to customer	156	160
Deferred Tax Assets, Lease Liabilities	8	0
Accrued pension and postretirement costs	0	7
State tax credit carryforwards	5	0
Contributions in aid of construction	8	7
Domestic - other	3	3
Valuation allowances	(4)	0
Total deferred tax assets	224	228
Deferred Tax Liabilities
Domestic plant - net	959	911
Regulatory assets	45	50
Accrued pension and postretirement costs	2	0
Lease right-of-use assets	7	0
Domestic - other	3	2
Total deferred tax liabilities	1,016	963
Net deferred tax liability	$ 792	$ 735

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, 2019	Dec. 31, 2018	Dec. 31, 2017
Credit carryforwards
Deferred tax asset credit carryforwards	$ 402	$ 392
Deferred Tax Assets, Valuation Allowances	834	808
Tax Cuts And Jobs Act [Member]
Credit carryforwards
Credit Carryforward Valuation Allowance Foreign Tax Credits			$ 122
Taxable Deemed Dividend			462
Deferred Tax Assets, Foreign Tax Credit Carryforwards			205
Permanently reinvested cumulative undistributed foreign earnings	7,500
Valuation Allowances and Reserves (Details) [Roll Forward]
Increase of the valuation allowance as a result of the expected future utilization of foreign tax credits			145
Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	133
Credit Carryforward Valuation Allowance Investment Tax Credit	0
Alternative Minimum Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	8
Credit Carryforward Valuation Allowance Alternative Minimum 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	18
Credit Carryforward Valuation Allowance Other	0
Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	24
Credit Carryforward Valuation Allowance Other	(6)
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	808	838	593
Additions charged to income	31	26	256
Additions charged to other accounts	0	0	0
Deductions	5	56	11
Balance at end of period	834	808	838
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		19
Increase of the valuation allowance as a result of the expected future utilization of foreign tax credits			145
Increase of the valuation allowance as a result of the reduction in the U.S. federal corporate income tax rate			62
LG And E And KU Energy LLC [Member]
Credit carryforwards
State tax credit carryforwards	19	1
Deferred tax asset credit carryforwards	162	169
Deferred Tax Assets, Valuation Allowances	6	8
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	133
Credit Carryforward Valuation Allowance Investment Tax Credit	0
LG And E And KU Energy LLC [Member] | Alternative Minimum Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	7
Credit Carryforward Valuation Allowance Alternative Minimum Tax Credit	0
LG And E And KU Energy LLC [Member] | Recycling Tax Credit [Member] | State [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	18
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	22
Credit Carryforward Valuation Allowance Other	(6)
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	8	8	11
Additions charged to other accounts	3	0	4
Deductions	5	0	7
Balance at end of period	6	8	$ 8
Louisville Gas And Electric Co [Member]
Credit carryforwards
State tax credit carryforwards	14	0
Deferred Tax Assets, Valuation Allowances	14	0
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	14
Deferred Tax Assets, Valuation Allowances	14
Kentucky Utilities Co [Member]
Credit carryforwards
State tax credit carryforwards	5	0
Deferred Tax Assets, Valuation Allowances	4	$ 0
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, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Expense (Benefit)
Current - Federal	$ (10)	$ (19)	$ 6
Current - State	19	17	25
Current - Foreign	91	104	45
Total Current Expense	100	102	76
Deferred - Federal	139	203	532
Deferred - State	76	100	88
Deferred - Foreign	123	107	133
Total Deferred Expense (Benefit), excluding operating loss carry forwards	338	410	753
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	7	(20)	(16)
Deferred - State	(33)	(31)	(26)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(26)	(51)	(42)
Total income tax from continuing operations	409	458	784
Income tax expense [Abstract]
Total income tax expense - Federal	133	161	519
Total income tax expense - State	62	86	87
Total income tax expense - Foreign	214	211	178
Total income tax from continuing operations	409	458	784
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Other comprehensive income	(93)	(6)	(34)
Valuation allowance on state deferred taxes recorded to other comprehensive income	0	0	(1)
Total income tax expense (benefits) excluded from incomes taxes from continuing operations	(93)	(6)	(35)
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	453	480	669
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	45	40	46
Valuation allowance adjustments	22	21	36
Impact of lower U.K. income tax rates	(25)	(25)	(176)
U.S. income tax on foreign earnings - net of foreign tax credit	2	3	47
Foreign income return adjustments	0	0	(8)
Impact of the United Kingdom Finance Acts on deferred tax balances	(14)	(13)	(16)
Depreciation and other items not normalized	(10)	(11)	(10)
Amortization of excess deferred federal and state income taxes	(40)	(37)	0
Interest benefit on United Kingdom financing entities	(12)	(17)	(16)
Deferred tax impact of U.S. tax reform	0	0	220
Deferred tax impact of Kentucky tax reform	0	9	0
Kentucky recycling credit, net of federal income tax expense	(18)	0	0
Other	6	8	(8)
Total increase (decrease)	(44)	(22)	115
Total income tax from continuing operations	$ 409	$ 458	$ 784
Effective income tax rate	19.00%	20.00%	41.00%
Income Tax Reconciliation Valuation Allowance Foreign Tax Credits			$ 23
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized	$ 25	$ 24	16
Deferred Income Tax Expense Benefit Foreign Pension Contribution			35
Taxes, other than income
State gross receipts	107	103	102
State capital stock	0	0	(6)
Foreign property	127	134	127
Domestic property and other	79	75	69
Total	313	312	292
Income Tax Reconciliation Valuation Allowance Foreign Tax Credits			23
Tax Cuts And Jobs Act [Member]
Income Tax Expense (Benefit)
Deferred Income Tax Expense (Benefit) Tax Rate Change			220
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations			321
Income tax expense [Abstract]
Total income tax from continuing operations			321
Increase (decrease) due to:
Total income tax from continuing operations			321
Deferred Income Tax Expense Benefit Tax Reform			83
Taxable Deemed Dividend			462
Taxes, other than income
Deferred Income Tax Expense (Benefit) Net Operating Loss			162
Deferred Income Tax Benefit Foreign Tax Credits			60
Deferred Tax Assets, Foreign Tax Credit Carryforwards			205
Valuation Rollfoward Specific Transaction Additions Foreign Tax Credits			145
Credit Carryforward Valuation Allowance Foreign Tax Credits			122
Credit Carryforward Expected Realization Foreign Tax Credits			83
PPL Electric Utilities Corp [Member]
Income Tax Expense (Benefit)
Current - Federal	44	2	(65)
Current - State	15	9	20
Total Current Expense	59	11	(45)
Deferred - Federal	51	96	234
Deferred - State	39	37	29
Total Deferred Expense (Benefit), excluding operating loss carry forwards	90	133	263
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	(8)	(5)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	(8)	(5)
Total income tax from continuing operations	149	136	213
Income tax expense [Abstract]
Total income tax expense - Federal	95	90	164
Total income tax expense - State	54	46	49
Total income tax from continuing operations	149	136	213
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	127	119	201
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	47	43	36
Depreciation and other items not normalized	(10)	(11)	(8)
Amortization of excess deferred federal and state income taxes	(18)	(17)	0
Deferred tax impact of U.S. tax reform	0	0	(13)
Other	3	2	(3)
Total increase (decrease)	22	17	12
Total income tax from continuing operations	$ 149	$ 136	$ 213
Effective income tax rate	24.60%	24.00%	37.00%
Taxes, other than income
State gross receipts	$ 107	$ 103	$ 102
Domestic property and other	5	6	5
Total	112	109	107
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member]
Income Tax Expense (Benefit)
Deferred Income Tax Expense (Benefit) Tax Rate Change		(13)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations			(13)
Income tax expense [Abstract]
Total income tax from continuing operations			(13)
Increase (decrease) due to:
Total income tax from continuing operations			(13)
LG And E And KU Energy LLC [Member]
Income Tax Expense (Benefit)
Current - Federal	20	31	74
Current - State	0	4	6
Total Current Expense	20	35	80
Deferred - Federal	81	65	268
Deferred - State	5	34	32
Total Deferred Expense (Benefit), excluding operating loss carry forwards	86	99	300
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	(2)	(2)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	(2)	(2)
Total income tax from continuing operations	103	129	375
Income tax expense [Abstract]
Total income tax expense - Federal	98	91	337
Total income tax expense - State	5	38	38
Total income tax from continuing operations	103	129	375
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Other comprehensive income	(1)	5	(10)
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	120	121	242
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	23	22	26
Valuation allowance adjustments	(23)	(20)	(2)
Amortization of investment tax credit	(3)	(3)	(3)
Deferred tax impact of U.S. tax reform	0	0	112
Deferred tax impact of Kentucky tax reform	0	9	0
Kentucky recycling credit, net of federal income tax expense	(18)	0	0
Other	4	0	0
Total increase (decrease)	(17)	8	133
Total income tax from continuing operations	$ 103	$ 129	$ 375
Effective income tax rate	18.00%	22.50%	54.30%
Taxes, other than income
Domestic property and other	$ 74	$ 70	$ 65
Total	74	70	65
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member]
Income Tax Expense (Benefit)
Deferred Income Tax Expense (Benefit) Tax Rate Change		108
Deferred Income Tax Expense (Benefit) Expiring Tax Credit		4
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations			112
Income tax expense [Abstract]
Total income tax from continuing operations			112
Increase (decrease) due to:
Total income tax from continuing operations			112
Deferred Income Tax Expense Benefit Tax Reform		112
Louisville Gas And Electric Co [Member]
Income Tax Expense (Benefit)
Current - Federal	4	0	0
Current - State	4	4	5
Total Current Expense	8	4	5
Deferred - Federal	46	51	112
Deferred - State	10	10	14
Total Deferred Expense (Benefit), excluding operating loss carry forwards	56	61	126
Amortization of investment tax credit	(1)	(1)	(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	0	1
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	0	1
Total income tax from continuing operations	63	64	131
Income tax expense [Abstract]
Total income tax expense - Federal	49	50	112
Total income tax expense - State	14	14	19
Total income tax from continuing operations	63	64	131
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	62	62	120
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	12	11	14
Valuation allowance adjustments	14	0	0
Amortization of excess deferred federal and state income taxes	(10)	(8)	(1)
Kentucky recycling credit, net of federal income tax expense	(14)	0	0
Other	(1)	(1)	(2)
Total increase (decrease)	1	2	11
Total income tax from continuing operations	$ 63	$ 64	$ 131
Effective income tax rate	21.40%	21.50%	38.10%
Taxes, other than income
Domestic property and other	$ 39	$ 36	$ 33
Total	39	36	33
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member]
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations			0
Income tax expense [Abstract]
Total income tax from continuing operations			0
Increase (decrease) due to:
Total income tax from continuing operations			0
Kentucky Utilities Co [Member]
Income Tax Expense (Benefit)
Current - Federal	35	22	0
Current - State	5	6	7
Total Current Expense	40	28	7
Deferred - Federal	28	40	138
Deferred - State	13	10	16
Total Deferred Expense (Benefit), excluding operating loss carry forwards	41	50	154
Amortization of investment tax credit	(2)	(2)	(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	79	76	159
Income tax expense [Abstract]
Total income tax expense - Federal	61	60	136
Total income tax expense - State	18	16	23
Total income tax from continuing operations	79	76	159
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	78	76	146
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	15	13	15
Valuation allowance adjustments	4	0	0
Amortization of investment tax credit	(2)	(2)	(2)
Amortization of excess deferred federal and state income taxes	(13)	(12)	(1)
Kentucky recycling credit, net of federal income tax expense	(4)	0	0
Other	1	1	1
Total increase (decrease)	1	0	13
Total income tax from continuing operations	$ 79	$ 76	$ 159
Effective income tax rate	21.20%	21.00%	38.00%
Taxes, other than income
Domestic property and other	$ 35	$ 34	$ 32
Total	$ 35	$ 34	32
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member]
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations			0
Income tax expense [Abstract]
Total income tax from continuing operations			0
Increase (decrease) due to:
Total income tax from continuing operations			$ 0

Income and Other Taxes (Unrecog

Income and Other Taxes (Unrecognized to End) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)Integer	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	4
Deferred Income Tax Expense (Benefit)	$ 338	$ 410	$ 753
Increase (Decrease) in Regulatory Assets and Liabilities	$ 88	(13)	12
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2015 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2015 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	2015 and prior
LKE [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Deferred Income Tax Expense (Benefit)		9
LGE [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities		16
KU [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities		19
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)	$ 90	133	263
Increase (Decrease) in Regulatory Assets and Liabilities	$ 43	19	5
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2015 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	2015 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)	$ 86	99	300
Increase (Decrease) in Regulatory Assets and Liabilities	$ 45	(32)	7
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	2015 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
LG And E And KU Energy LLC [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Deferred Income Tax Expense (Benefit)	$ 9
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	16
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 19
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)	$ 56	61	126
Increase (Decrease) in Regulatory Assets and Liabilities	$ 19	(5)	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	2015 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
Louisville Gas And Electric Co [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 16
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)	$ 41	50	154
Increase (Decrease) in Regulatory Assets and Liabilities	$ 26	$ (27)	$ 2
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2015 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
Kentucky Utilities Co [Member] | Kentucky tax reform [Member]
Income Tax Examination (Details) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 19

Utility Rate Regulation (Regula

Utility Rate Regulation (Regulatory Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 67	$ 36
Noncurrent Regulatory Assets	1,492	1,673
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	8	12
Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	13	11
Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	32	10
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	10	0
Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	3
Noncurrent Regulatory Assets	4	10
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	800	963
Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	39	56
Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	41	45
Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	20
Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	81	87
Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	220	200
AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	279	273
Act 129 compliance rider [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	6	19
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	26	11
Noncurrent Regulatory Assets	726	824
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	13	11
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	3	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	10	0
PPL Electric Utilities Corp [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Noncurrent Regulatory Assets	0	3
PPL Electric Utilities Corp [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	467	558
PPL Electric Utilities Corp [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	15	22
PPL Electric Utilities Corp [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	18	22
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	220	200
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	6	19
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	41	25
Noncurrent Regulatory Assets	766	849
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	8	12
LG And E And KU Energy LLC [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	32	10
LG And E And KU Energy LLC [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	1	3
Noncurrent Regulatory Assets	4	7
LG And E And KU Energy LLC [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	333	405
LG And E And KU Energy LLC [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	24	34
LG And E And KU Energy LLC [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	23	23
LG And E And KU Energy LLC [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	20
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	81	87
LG And E And KU Energy LLC [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	279	273
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	25	21
Noncurrent Regulatory Assets	380	431
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	8	12
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	16	7
Louisville Gas And Electric Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	1	2
Noncurrent Regulatory Assets	1	1
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	206	249
Louisville Gas And Electric Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	14	20
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	14	15
Louisville Gas And Electric Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	20
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	47	51
Louisville Gas And Electric Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	76	75
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	16	4
Noncurrent Regulatory Assets	386	418
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	16	3
Kentucky Utilities Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	1
Noncurrent Regulatory Assets	3	6
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	127	156
Kentucky Utilities Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	10	14
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	9	8
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	34	36
Kentucky Utilities Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 203	$ 198

Utility Rate Regulation (Regu_2

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 115	$ 122
Noncurrent regulatory liabilities	2,572	2,714
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	23	33
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	16
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	9	27
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	0
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	61	20
Noncurrent regulatory liabilities	0	41
Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	5
Generation formula rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	7
Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	640	674
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	51	59
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,756	1,826
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	51	37
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	68	72
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	14
Noncurrent regulatory liabilities	6	5
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	96	74
Noncurrent regulatory liabilities	599	675
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	23	33
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3
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	9	27
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3
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	59	3
Noncurrent regulatory liabilities	0	41
PPL Electric Utilities Corp [Member] | Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	5
PPL Electric Utilities Corp [Member] | Generation formula rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	588	629
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	11	5
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	19	48
Noncurrent regulatory liabilities	1,973	2,039
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	16
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	0
LG And E And KU Energy LLC [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	17
LG And E And KU Energy LLC [Member] | Generation formula rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	7
LG And E And KU Energy LLC [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	640	674
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	51	59
LG And E And KU Energy LLC [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,168	1,197
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	40	32
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	68	72
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	8
Noncurrent regulatory liabilities	6	5
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	17
Noncurrent regulatory liabilities	883	915
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	6
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] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	7
Louisville Gas And Electric Co [Member] | Generation formula rate [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	266	279
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	35	41
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	544	557
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	34	36
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	4
Noncurrent regulatory liabilities	4	2
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	31
Noncurrent regulatory liabilities	1,090	1,124
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	10
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	0
Kentucky Utilities Co [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	10
Kentucky Utilities Co [Member] | Generation formula rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	7
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	374	395
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	16	18
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	624	640
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	40	32
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	34	36
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	4
Noncurrent regulatory liabilities	$ 2	$ 3

Utility Rate Regulation (Regu_3

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 88	$ (13)	$ 12
Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period	15 years
Tax Cuts And Jobs Act [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 2,185		2,185
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	$ 51	45
LGE [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period	12 months
LGE [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.725%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Term, in years, of the gas service rider program	5 years
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	9.725%
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	9.725%
PPL Electric Utilities Corp [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period	5 years
Increase (Decrease) in Regulatory Assets and Liabilities	$ 43	19	5
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] | Tax Cuts And Jobs Act [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 1,019		1,019
LG And E And KU Energy LLC [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 45	(32)	7
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	$ 51	45
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 1,166		1,166
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 Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.725%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Term, in years, of the gas service rider program	5 years
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	9.725%
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	9.725%
Louisville Gas And Electric Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 19	(5)	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	$ 29	25
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 Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.725%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Term, in years, of the gas service rider program	5 years
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	9.725%
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 532		532
Kentucky Utilities Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 26	(27)	2
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	$ 22	$ 20
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	9.725%
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 634		$ 634

Utility Rate Regulation (Regu_4

Utility Rate Regulation (Regulatory Matters) (Details) - USD ($) $ in Millions	Apr. 30, 2019	Mar. 01, 2019	Sep. 28, 2018	Sep. 30, 2018	Jun. 30, 2018	Dec. 31, 2019	Dec. 31, 2019
LKE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Estimated Total Revenue Increase	$ 187
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities Proposed Return On Equity Percentage		9.725%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Revenue Increase Due To Elimination Of TCJA Bill Credit				$ 40
Public Utilities Proposed Rate Increase Decrease Amount		$ 4
Public Utilities, Approved Rate Increase (Decrease), Amount	2
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Revenue Increase Due To Elimination Of TCJA Bill Credit				12
Public Utilities Proposed Rate Increase Decrease Amount		20
Public Utilities, Approved Rate Increase (Decrease), Amount	19
LGE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Estimated Total Revenue Increase	73
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Revenue Increase Due To Elimination Of TCJA Bill Credit				$ 58
Public Utilities Proposed Rate Increase Decrease Amount		$ 58
Public Utilities, Approved Rate Increase (Decrease), Amount	56
KU [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Estimated Total Revenue Increase	$ 114
PPL Electric Utilities Corp [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Amortization period for the deferred recovery of a regulatory asset						5 years
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Tax Cuts And Jobs Act [Member] | Noncurrent [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Approved Amount Of Rate Reduction Due To TCJA						$ 41
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity			10.42%
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			$ 35
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			25
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			$ 112
TCJA customer refund [Member] | PPL Electric Utilities Corp [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Approved Amount Of Rate Reduction Due To TCJA					$ 43		$ 16

Utility Rate Regulation (Other)

Utility Rate Regulation (Other) (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.2	$ 1.3	$ 1.3
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.2	$ 1.3	$ 1.3

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)	Dec. 31, 2019GBP (£)	Dec. 31, 2018USD ($)	Dec. 31, 2018GBP (£)	Dec. 31, 2017USD ($)
U.K. [Member]
Financing Activities [Line Items]
Capacity | £		£ 1,155
Borrowed | £		243		£ 195
Letters of credit and commercial paper issued | £		4		4
Unused capacity	$ 1,200	908
U.K. [Member] | Uncommitted Credit Facilities [Member]
Financing Activities [Line Items]
Capacity | £		100
Borrowed | £		0		0
Letters of credit and commercial paper issued | £		4		4
Unused capacity | £		96
WPD PLC [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £		210
Borrowed	$ 200	155	$ 200	157
Letters of credit and commercial paper issued | £		0		£ 0
Unused capacity | £		£ 55
Minimum interest coverage ratio allowed under the credit facility	3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing	2.52%	2.52%	3.17%	3.17%
WPD South West [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £		£ 245
Borrowed	$ 51	40		£ 0
Letters of credit and commercial paper issued | £		0		0
Unused capacity | £		£ 205
Minimum interest coverage ratio allowed under the credit facility	3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing	1.09%	1.09%
WPD East Midlands [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £		£ 300
Borrowed		0	$ 48	38
Letters of credit and commercial paper issued | £		0		£ 0
Unused capacity | £		£ 300
Minimum interest coverage ratio allowed under the credit facility	3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing			1.12%	1.12%
WPD West Midlands [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £		£ 300
Borrowed	$ 62	48		£ 0
Letters of credit and commercial paper issued | £		0		£ 0
Unused capacity | £		£ 252
Minimum interest coverage ratio allowed under the credit facility	3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing	1.11%	1.11%
PPL Capital Funding [Member] | U.S. [Member]
Financing Activities [Line Items]
Capacity	$ 1,550
Borrowed	0		$ 0
Letters of credit and commercial paper issued	465		684
Unused capacity	1,085
PPL Capital Funding [Member] | U.S. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	1,450
Borrowed			0
Letters of credit and commercial paper issued	450		669
Unused capacity	$ 1,000
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	$ 100
Borrowed	0		0
Letters of credit and commercial paper issued	15		15
Unused capacity	85
Potential capacity increase	$ 30
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 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%
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		200
Letters of credit and commercial paper issued	238		279
Unused capacity	262
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	500
Borrowed	0		0
Letters of credit and commercial paper issued	238		279
Unused capacity	$ 262
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase	$ 250
LGE [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	0				$ 200
Borrowed	0		200
Letters of credit and commercial paper issued	0		$ 0
Unused capacity	0
Interest rate on outstanding borrowing			2.97%	2.97%
KU [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0		$ 0
Letters of credit and commercial paper issued	150		433
Unused capacity	250
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0		0
Letters of credit and commercial paper issued	150		235
Unused capacity	$ 250
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]
Capacity	0
Borrowed	0		0
Letters of credit and commercial paper issued	0		198
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase	$ 250
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	650
Borrowed	0		0
Letters of credit and commercial paper issued	1		1
Unused capacity	$ 649
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
LG And E And KU Energy LLC [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	$ 0
Borrowed	0		0
Letters of credit and commercial paper issued	0		0
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
LG And E And KU Energy LLC [Member] | LGE [Member]
Financing Activities [Line Items]
Capacity	$ 500
Borrowed	0		200
Letters of credit and commercial paper issued	238		279
Unused capacity	262
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	238		279
Unused capacity	$ 262
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] | LGE [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	0		200
Borrowed	0		200
Letters of credit and commercial paper issued	0		$ 0
Unused capacity	0
Interest rate on outstanding borrowing			2.97%	2.97%
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	150		433
Unused capacity	250
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	150		235
Unused capacity	$ 250
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]
Capacity	0
Borrowed	0		0
Letters of credit and commercial paper issued	0		198
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase	$ 250
Louisville Gas And Electric Co [Member]
Financing Activities [Line Items]
Capacity	500
Borrowed	0		200
Letters of credit and commercial paper issued	238		279
Unused capacity	262
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	238		279
Unused capacity	$ 262
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase	$ 250
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	0		200
Borrowed	0		200
Letters of credit and commercial paper issued	0		$ 0
Unused capacity	0
Interest rate on outstanding borrowing			2.97%	2.97%
Kentucky Utilities Co [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0		$ 0
Letters of credit and commercial paper issued	150		433
Unused capacity	250
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0		0
Letters of credit and commercial paper issued	150		235
Unused capacity	$ 250
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]
Capacity	0
Borrowed	0		0
Letters of credit and commercial paper issued	0		$ 198
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase	$ 250

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Short-term Debt [Line Items]
Capacity	$ 2,850
Commercial paper issuances	838	$ 1,183
Unused capacity	$ 2,012
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.13%	2.82%
Capacity	$ 1,500
Commercial paper issuances	450	$ 669
Unused capacity	$ 1,050
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	2.07%	2.94%
Capacity	$ 350
Commercial paper issuances	238	$ 279
Unused capacity	$ 112
KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.02%	2.94%
Capacity	$ 350
Commercial paper issuances	150	$ 235
Unused capacity	$ 200
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	2.07%	2.94%
Capacity	$ 350
Commercial paper issuances	238	$ 279
Unused capacity	$ 112
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.02%	2.94%
Capacity	$ 350
Commercial paper issuances	150	$ 235
Unused capacity	$ 200
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.07%	2.94%
Capacity	$ 350
Commercial paper issuances	238	$ 279
Unused capacity	$ 112
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.02%	2.94%
Capacity	$ 350
Commercial paper issuances	150	$ 235
Unused capacity	$ 200

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) £ in Millions, $ in Millions	1 Months Ended				6 Months Ended	12 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019GBP (£)	Apr. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2019GBP (£)	Sep. 30, 2019GBP (£)	Sep. 17, 2019	Jun. 30, 2019GBP (£)	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
Principal outstanding						$ 22,002					$ 20,694
Unamortized premium and (discount), net						5					9
Unamortized debt issuance costs						(126)					(120)
Total Long-term Debt						21,893					20,599
Less current portion of Long-term debt						1,172					530
Long-term Debt						20,721					20,069
Aggregate maturities of long-term debt (Details) [Abstract]
2019						1,169
2020						1,574
2021						1,274
2022						2,254
2023						932
Thereafter						14,799
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						423	£ 327
WPD South Wales [Member] | Index-linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £										£ 50
Stated interest rate					2.189%					2.189%
Proceeds from debt, including premium net of debt issuance costs					$ 63
WPD West Midlands [Member] | Index-linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £								£ 250
Stated interest rate	1.75%							1.75%
Proceeds from Debt, Net of Issuance Costs | £		£ 245
Proceeds from debt, including premium net of debt issuance costs	$ 301
PPL Electric [Member] | Senior Secured Bonds 5.15% Series Due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 100
Stated interest rate						5.15%	5.15%
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						$ 10,100					9,400
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 Due 2049 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 400
Stated interest rate	3.00%							3.00%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt	$ 390
LGE [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.85%
LGE [Member] | Environmental Facilities Revenue Refunding Bonds, 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 31
Stated interest rate					1.65%					1.65%
LGE [Member] | Environmental Facilities Revenue Bonds, 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 35
Stated interest rate					1.65%					1.65%
LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate									1.75%
LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Interest Rate Conversion [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 40
LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien						$ 5,300					5,100
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
LGE [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2049 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 400
Stated interest rate			4.25%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt			$ 396
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						$ 700
Aggregate amount of tax-exempt revenue bonds in a variable rate mode						181
KU [Member] | Environmental Facilities Revenue Bonds, 2004 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 50
Stated interest rate	1.75%							1.75%
KU [Member] | Pollution Control Revenue Bonds, 2016 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 96
Stated interest rate	1.55%							1.55%
KU [Member] | Environmental Facilities Revenue Bonds, 2006 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 54
Stated interest rate	1.20%							1.20%
KU [Member] | Environmental Facilities Revenue Bonds, 2008 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 78
Stated interest rate	1.20%							1.20%
KU [Member] | Solid Waste Disposal Facility Revenue Bonds, 2000 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 13
Stated interest rate	1.30%							1.30%
KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien						$ 6,600					6,300
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 Bond Due 2045 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 300
Stated interest rate			4.375%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt			$ 303
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						$ 26	£ 20
U.S. [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 13,960					13,160
U.S. [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.88%	3.88%
Principal outstanding						$ 4,325					4,325
U.S. [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.95%	3.95%
Principal outstanding						$ 8,705					7,705
U.S. [Member] | Junior Subordinated Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						5.24%	5.24%
Principal outstanding						$ 930					930
U.S. [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate
Principal outstanding						$ 0					200
U.K. [Member]
Debt Instrument [Line Items]
Principal outstanding						8,042					7,534
Fair market value adjustments						12					16
Long-term Debt (Numeric) [Abstract]
Principal amount that may be put back to the issuer						$ 7,400	£ 5,700
U.K. [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						4.97%	4.97%
Principal outstanding						$ 6,874					6,471
Long-term Debt (Numeric) [Abstract]
Principal amount that may be redeemed in total but not in part						$ 291	£ 225
U.K. [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						2.18%	2.18%
Principal outstanding						$ 64					0
U.K. [Member] | Index-linked Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						1.45%	1.45%
Principal outstanding						$ 1,104					1,063
PPL Electric Utilities Corp [Member]
Debt Instrument [Line Items]
Principal outstanding						4,039					3,739
Unamortized discount						(24)					(18)
Unamortized debt issuance costs						(30)					(27)
Total Long-term Debt						3,985					3,694
Less current portion of Long-term debt						0					0
Long-term Debt						3,985					3,694
Aggregate maturities of long-term debt (Details) [Abstract]
2019						0
2020						400
2021						474
2022						90
2023						0
Thereafter						3,075
PPL Electric Utilities Corp [Member] | Senior Secured Bonds 5.15% Series Due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 100
Stated interest rate						5.15%	5.15%
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						4.08%	4.08%
Principal outstanding						$ 4,039					3,739
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						10,100					9,400
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]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 400
Stated interest rate				3.00%
Proceeds from Debt, Net of Issuance Costs				$ 390
LG And E And KU Energy LLC [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 6,041					5,541
Debt Instrument, Unamortized Premium						5					0
Unamortized discount						(12)					(13)
Unamortized debt issuance costs						(32)					(26)
Total Long-term Debt						6,002					5,502
Less current portion of Long-term debt						975					530
Long-term Debt						5,027					4,972
Aggregate maturities of long-term debt (Details) [Abstract]
2019						975
2020						674
2021						0
2022						13
2023						0
Thereafter						$ 4,379
LG And E And KU Energy LLC [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.97%	3.97%
Principal outstanding						$ 725					725
LG And E And KU Energy LLC [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate
Principal outstanding						$ 0					200
LG And E And KU Energy LLC [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.84%	3.84%
Principal outstanding						$ 4,666					3,966
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						700
Aggregate amount of tax-exempt revenue bonds in a variable rate mode						$ 181
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.69%	3.69%
Principal outstanding						$ 650					650
LG And E And KU Energy LLC [Member] | LGE [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.85%
LG And E And KU Energy LLC [Member] | LGE [Member] | Environmental Facilities Revenue Refunding Bonds, 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 31
Stated interest rate					1.65%					1.65%
LG And E And KU Energy LLC [Member] | LGE [Member] | Environmental Facilities Revenue Bonds, 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 35
Stated interest rate					1.65%					1.65%
LG And E And KU Energy LLC [Member] | LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate									1.75%
LG And E And KU Energy LLC [Member] | LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Interest Rate Conversion [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 40
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						$ 5,300					5,100
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] | LGE [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2049 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 400
Stated interest rate			4.25%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt			$ 396
LG And E And KU Energy LLC [Member] | KU [Member] | Environmental Facilities Revenue Bonds, 2004 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 50
Stated interest rate	1.75%							1.75%
LG And E And KU Energy LLC [Member] | KU [Member] | Pollution Control Revenue Bonds, 2016 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 96
Stated interest rate	1.55%							1.55%
LG And E And KU Energy LLC [Member] | KU [Member] | Environmental Facilities Revenue Bonds, 2006 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 54
Stated interest rate	1.20%							1.20%
LG And E And KU Energy LLC [Member] | KU [Member] | Environmental Facilities Revenue Bonds, 2008 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 78
Stated interest rate	1.20%							1.20%
LG And E And KU Energy LLC [Member] | KU [Member] | Solid Waste Disposal Facility Revenue Bonds, 2000 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 13
Stated interest rate	1.30%							1.30%
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						$ 6,600					6,300
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 Bond Due 2045 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 300
Stated interest rate			4.375%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt			$ 303
Louisville Gas And Electric Co [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 2,024					1,824
Unamortized discount						(4)					(4)
Unamortized debt issuance costs						(15)					(11)
Total Long-term Debt						2,005					1,809
Less current portion of Long-term debt						0					434
Long-term Debt						2,005					1,375
Aggregate maturities of long-term debt (Details) [Abstract]
2019						0
2020						292
2021						0
2022						0
2023						0
Thereafter						$ 1,732
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			$ 128
Stated interest rate			1.85%
Louisville Gas And Electric Co [Member] | Environmental Facilities Revenue Refunding Bonds, 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 31
Stated interest rate					1.65%					1.65%
Louisville Gas And Electric Co [Member] | Environmental Facilities Revenue Bonds, 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 35
Stated interest rate					1.65%					1.65%
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate									1.75%
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Interest Rate Conversion [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 40
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate
Principal outstanding						$ 0					200
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.73%	3.73%
Principal outstanding						$ 2,024					1,624
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						$ 5,300					5,100
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						$ 392
Aggregate amount of tax-exempt revenue bonds in a variable rate mode						148
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2049 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 400
Stated interest rate			4.25%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt			$ 396
Kentucky Utilities Co [Member]
Debt Instrument [Line Items]
Principal outstanding						2,642					2,342
Debt Instrument, Unamortized Premium						5					0
Unamortized discount						(8)					(8)
Unamortized debt issuance costs						(16)					(13)
Total Long-term Debt						2,623					2,321
Less current portion of Long-term debt						500					96
Long-term Debt						2,123					2,225
Aggregate maturities of long-term debt (Details) [Abstract]
2019						500
2020						132
2021						0
2022						13
2023						0
Thereafter						$ 1,997
Kentucky Utilities Co [Member] | Environmental Facilities Revenue Bonds, 2004 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 50
Stated interest rate	1.75%							1.75%
Kentucky Utilities Co [Member] | Pollution Control Revenue Bonds, 2016 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 96
Stated interest rate	1.55%							1.55%
Kentucky Utilities Co [Member] | Environmental Facilities Revenue Bonds, 2006 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 54
Stated interest rate	1.20%							1.20%
Kentucky Utilities Co [Member] | Environmental Facilities Revenue Bonds, 2008 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 78
Stated interest rate	1.20%							1.20%
Kentucky Utilities Co [Member] | Solid Waste Disposal Facility Revenue Bonds, 2000 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 13
Stated interest rate	1.30%							1.30%
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.93%	3.93%
Principal outstanding						$ 2,642					2,342
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						$ 6,600					$ 6,300
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						$ 308
Aggregate amount of tax-exempt revenue bonds in a variable rate mode						$ 33
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 300
Stated interest rate			4.375%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt			$ 303

Financing Activities Financing

Financing Activities Financing Activities- Equity Securities (Details) $ in Millions		1 Months Ended			12 Months Ended
		Nov. 30, 2019USD ($)shares	Sep. 30, 2018USD ($)shares	May 31, 2018counterpartiesshares	Dec. 31, 2019USD ($)shares	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)shares	Feb. 28, 2018USD ($)
Equity Programs [Line Items]
Issuance of common stock | $					$ 1,167	$ 698	$ 453
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]				46,910,000	26,925,000	13,667,000
Common Stock [Member] | Forward Sale Agreement [Member]
Equity Programs [Line Items]
Issuance of common stock | $		$ 1,100	$ 520
Common stock shares issued		43,250,000	20,000,000
Total Number Of Shares Issued In Forward Sales Agreements And Overallotment Option				63,250,000
Number of Counterparties | counterparties				2
Forward Contract Indexed to Issuer's Equity, Shares				55,000,000
Over-Allotment Option [Member] | Common Stock [Member] | Forward Sale Agreement [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares				8,250,000
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%
Issuance of common stock | $						$ 119
Common stock shares issued					0	42,000,000
[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	Feb. 14, 2020	Nov. 30, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)		$ 0.4125	$ 1.65	$ 1.64	$ 1.58
Annualized current quarterly common stock dividend (in dollars per share)		$ 1.65
Deferred Interest Payment			$ 0
Subsequent Event [Member]
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)	$ 0.415
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.66
LKE [Member]
Distributions [Line Items]
Restricted net assets at end of period			3,000
Unrestricted assets at the end of period			$ 3,300
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			$ 3,300
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			$ 1,500
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			$ 1,800
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, 2019	Jan. 01, 2019	Dec. 31, 2018
Lease, Cost [Abstract]
Operating lease cost	$ 33
Short-term lease cost	7
Total lease cost	40
Operating cash flows from operating leases	29
Right-of-use asset obtained in exchange for new operating lease liabilities	46
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020	29
2021	22
2022	17
2023	15
2024	12
Thereafter	27
Total	$ 122
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.48%
Weighted-average remaining lease term (in years)	8 years
2019			$ 26
2020			21
2021			15
2022			13
2023			8
Thereafter			33
Total			116
Other Current Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Current lease liabilities	$ 26	$ 23
Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	78	67
Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	96	81
LG And E And KU Energy LLC [Member]
Lease, Cost [Abstract]
Operating lease cost	25
Short-term lease cost	2
Total lease cost	27
Operating cash flows from operating leases	21
Right-of-use asset obtained in exchange for new operating lease liabilities	16
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020	18
2021	13
2022	9
2023	7
2024	6
Thereafter	8
Total	$ 61
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.96%
Weighted-average remaining lease term (in years)	5 years
2019			20
2020			15
2021			11
2022			7
2023			6
Thereafter			11
Total			70
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	18
LG And E And KU Energy LLC [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	39	46
LG And E And KU Energy LLC [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	47	56
Louisville Gas And Electric Co [Member]
Lease, Cost [Abstract]
Operating lease cost	12
Short-term lease cost	1
Total lease cost	13
Operating cash flows from operating leases	9
Right-of-use asset obtained in exchange for new operating lease liabilities	5
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020	7
2021	5
2022	4
2023	3
2024	2
Thereafter	3
Total	$ 24
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.89%
Weighted-average remaining lease term (in years)	5 years
2019			10
2020			6
2021			4
2022			3
2023			3
Thereafter			4
Total			30
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	9
Louisville Gas And Electric Co [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	15	18
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	18	23
Kentucky Utilities Co [Member]
Lease, Cost [Abstract]
Operating lease cost	13
Short-term lease cost	1
Total lease cost	14
Operating cash flows from operating leases	11
Right-of-use asset obtained in exchange for new operating lease liabilities	11
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020	11
2021	8
2022	5
2023	4
2024	4
Thereafter	4
Total	$ 36
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	4.01%
Weighted-average remaining lease term (in years)	5 years
2019			10
2020			9
2021			7
2022			4
2023			3
Thereafter			6
Total			$ 39
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	$ 10	9
Kentucky Utilities Co [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	23	26
Kentucky Utilities Co [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	$ 28	$ 31

Leases Leases - Lessor (Details

Leases Leases - Lessor (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Lessor, Lease, Description [Line Items]
2020	$ 13
2021	11
2022	5
2023	5
2024	3
Thereafter	12
Total	49
Lease income recognized	21
LG And E And KU Energy LLC [Member]
Lessor, Lease, Description [Line Items]
2020	7
2021	5
2022	0
2023	1
2024	0
Thereafter	0
Total	13
Lease income recognized	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	5
Kentucky Utilities Co [Member]
Lessor, Lease, Description [Line Items]
2020	7
2021	5
2022	0
2023	0
2024	0
Thereafter	0
Total	12
Lease income recognized	$ 8

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)	12 Months Ended
	Dec. 31, 2019USD ($)Integer$ / sharesshares	Dec. 31, 2018USD ($)$ / sharesshares	Dec. 31, 2017USD ($)$ / 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)	1,098,203
Granted (in shares)	479,428
Vested (in shares)	(429,258)
Forfeited (in shares)	(10,688)
Nonvested, end of period (in shares)	1,137,685	1,098,203
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 33.45
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	31.95	$ 30.58	$ 35.30
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	33.64
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	31.53
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.76	$ 33.45
Total fair value of units vested during the period | $	$ 13,000,000	$ 16,000,000	$ 20,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years	3 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)	840,124
Granted (in shares)	250,734
Vested (in shares)	0
Forfeited (in shares)	(351,466)
Nonvested, end of period (in shares)	739,392	840,124
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	$ 37.89
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.83	$ 38.26	$ 38.38
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	37.24
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.50	$ 37.89
Total fair value of units vested during the period | $		$ 3,000,000	$ 8,000,000
Period over which performance units fair value is recognized (in years)	3 years	3 years	3 years
Maximum payout percentage of target award	200.00%	200.00%	200.00%
Fair value assumptions and methodology [Abstract]
Expected option life (in years)	3 years	3 years	3 years
Expected stock volatility	17.57%	17.60%	17.40%
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	1 year	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	3 years	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year	1 year	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)	328,958
Granted (in shares)	241,807
Nonvested, end of period (in shares)	570,765	328,958
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	$ 32.86
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.89	$ 32.21	$ 32.42
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.02	$ 32.86
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)	2,914,525
Exercised (in shares)	(1,578,554)
Forfeited (in shares)	(5,028)
Outstanding at end of period (in shares)	1,330,943	2,914,525
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	$ 26.26
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares	26.31
Weighted average exercise price per share, forfeited (in dollars per share) | $ / shares	28.77
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares	$ 26.20	$ 26.26
Weighted average remaining contractual term (in years)	2 years 6 months
Aggregate total intrinsic value | $	$ 13,000,000
Cash received from exercise of stock options | $	53,000,000	$ 5,000,000	$ 19,000,000
Total intrinsic value of stock options exercised | $	11,000,000		8,000,000
All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	35,000,000	25,000,000	32,000,000
Income tax benefit | $	10,000,000	$ 10,000,000	$ 13,000,000
Unrecognized compensation expense | $	$ 14,000,000
Weighted-average period for recognition | Integer	1.9
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)	187,337
Transfer between registrants	(3,305)
Granted (in shares)	112,138
Vested (in shares)	(59,661)
Forfeited (in shares)	(6,649)
Nonvested, end of period (in shares)	229,860	187,337
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 33.09
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	33.06
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	32.33	$ 30	$ 35.45
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	33.77
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	31.01
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.61	$ 33.09
Total fair value of units vested during the period | $	$ 2,000,000	$ 2,000,000	$ 3,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years	3 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)	67,863
Granted (in shares)	24,158
Vested (in shares)	0
Forfeited (in shares)	(25,222)
Nonvested, end of period (in shares)	66,799	67,863
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	$ 37.86
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.68	$ 38.37	$ 38.37
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	36.92
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.43	$ 37.86
Period over which performance units fair value is recognized (in years)	3 years	3 years	3 years
Maximum payout percentage of target award	200.00%	200.00%	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	1 year	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	3 years	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year	1 year	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)	25,960
Granted (in shares)	23,234
Nonvested, end of period (in shares)	49,194	25,960
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	$ 32.96
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.76	$ 32.32	$ 34.41
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 31.92	$ 32.96
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	17.57%	17.60%	17.40%
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 | $	$ 12,000,000	$ 10,000,000	$ 18,000,000
Income tax benefit | $	3,000,000	$ 3,000,000	$ 8,000,000
Unrecognized compensation expense | $	$ 3,000,000
Weighted-average period for recognition | Integer	2.2
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)	133,030
Granted (in shares)	76,256
Vested (in shares)	(42,841)
Nonvested, end of period (in shares)	166,445	133,030
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 33.45
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.65	$ 30.98	$ 35.25
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	33.75
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.09	$ 33.45
Total fair value of units vested during the period | $	$ 1,000,000	$ 5,000,000	$ 4,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years	3 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)	148,996
Granted (in shares)	39,453
Vested (in shares)	0
Forfeited (in shares)	(57,916)
Nonvested, end of period (in shares)	130,533	148,996
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	$ 37.81
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.93	$ 38.32	$ 38.24
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	37.02
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.60	$ 37.81
Period over which performance units fair value is recognized (in years)	3 years	3 years	3 years
Maximum payout percentage of target award	200.00%	200.00%	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	1 year	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	3 years	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year	1 year	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)	69,620
Granted (in shares)	38,185
Nonvested, end of period (in shares)	107,805	69,620
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	$ 32.87
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.99	$ 32.28	$ 34.29
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.20	$ 32.87
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	17.57%	17.60%	17.40%
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 | $	$ 9,000,000	$ 8,000,000	$ 8,000,000
Income tax benefit | $	2,000,000	$ 2,000,000	$ 3,000,000
Unrecognized compensation expense | $	$ 1,000,000
Weighted-average period for recognition | Integer	1.5
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, 2019	Dec. 31, 2018	Dec. 31, 2017
Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	$ 50	$ 62	$ 65
Interest cost	164	156	168
Expected return on plan assets	(245)	(249)	(231)
Amortization of:
Prior service cost (credit)	8	10	10
Actuarial (gain) loss	56	84	69
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	33	63	81
Settlements	1	0	1
Termination benefits	0	0	1
Net periodic defined benefit costs (credits)	34	63	83
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	(1)	0	(1)
Net (gain) loss	(121)	157	27
Prior service costs (credit)	2	1	(1)
Amortization of: [Abstract]
Prior service (cost) credit	(8)	(10)	(10)
Actuarial gain (loss)	(56)	(84)	(69)
Total recognized in OCI and regulatory assets/liabilities	(184)	64	(54)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(150)	127	29
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(194)	90	(53)
Regulatory assets/liabilities	10	(26)	(1)
Total recognized in OCI and regulatory assets/liabilities	(184)	64	(54)
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	18	40	59
Pension Plan [Member] | U.K. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	68	82	76
Interest cost	187	185	178
Expected return on plan assets	(588)	(587)	(514)
Amortization of:
Prior service cost (credit)	1	0	0
Actuarial (gain) loss	92	151	144
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(240)	(169)	(116)
Settlements	0	0	0
Termination benefits	0	0	0
Net periodic defined benefit costs (credits)	(240)	(169)	(116)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	723	201	346
Prior service costs (credit)	0	13	0
Amortization of: [Abstract]
Prior service (cost) credit	(1)	0	0
Actuarial gain (loss)	(92)	(151)	(144)
Total recognized in OCI and regulatory assets/liabilities	630	63	202
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	390	(106)	86
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	630	63	202
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	(287)	(226)	(151)
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	6	7	7
Interest cost	22	21	23
Expected return on plan assets	(18)	(23)	(22)
Amortization of:
Prior service cost (credit)	(1)	(1)	(1)
Actuarial (gain) loss	1	0	1
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	10	4	8
Settlements	0	0	0
Termination benefits	0	0	0
Net periodic defined benefit costs (credits)	10	4	8
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	(18)	8	(28)
Prior service costs (credit)	0	0	8
Amortization of: [Abstract]
Prior service (cost) credit	1	1	1
Actuarial gain (loss)	(1)	0	(1)
Total recognized in OCI and regulatory assets/liabilities	(18)	9	(20)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(8)	13	(12)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(13)	20	(25)
Regulatory assets/liabilities	(5)	(11)	5
Total recognized in OCI and regulatory assets/liabilities	(18)	9	(20)
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	$ 8	2	5
PPL Electric Utilities Corp [Member]
Amortization of:
Amortization period for the deferred recovery of a regulatory asset	5 years
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]
Amortization period for the deferred recovery of a regulatory asset	5 years
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	$ (4)	4	12
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	4	(1)	0
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	22	25	24
Interest cost	66	63	68
Expected return on plan assets	(101)	(102)	(92)
Amortization of:
Prior service cost (credit)	8	9	8
Actuarial (gain) loss	22	35	31
Net periodic defined benefit costs (credits)	$ 17	$ 30	$ 39
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	$ 5	$ 11	$ 11
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss	(37)	40	30
Prior service costs (credit)	2	0	7
Amortization of: [Abstract]
Prior service (cost) credit	(8)	(9)	(8)
Actuarial gain (loss)	(22)	(35)	(32)
Total recognized in OCI and regulatory assets/liabilities	(65)	(4)	(3)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(48)	26	36
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	13	(25)	33
Regulatory assets/liabilities	(78)	21	(36)
Total recognized in OCI and regulatory assets/liabilities	(65)	(4)	(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	$ 12	$ 21	$ 28
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	$ 5	$ 11	$ 11
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements	5	6	5
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	8	8	9
Expected return on plan assets	(8)	(9)	(7)
Amortization of:
Prior service cost (credit)	1	1	1
Actuarial (gain) loss	(1)	0	0
Net periodic defined benefit costs (credits)	$ 4	$ 4	$ 7
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]
Net (gain) loss	$ (14)	$ 1	$ (14)
Prior service costs (credit)	0	0	8
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	(1)
Actuarial gain (loss)	1	0	0
Total recognized in OCI and regulatory assets/liabilities	(14)	0	(7)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(10)	4	0
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(7)	4	(2)
Regulatory assets/liabilities	(7)	(4)	(5)
Total recognized in OCI and regulatory assets/liabilities	(14)	0	(7)
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	$ 3	$ 5
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
LG And E And KU Energy LLC [Member] | LGE [Member] | Other Postretirement Benefits 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	$ (2)	$ (3)	$ (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]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	(2)	(3)	(4)
LG And E And KU Energy LLC [Member] | KU [Member] | Other Postretirement Benefits 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	(1)	(2)	(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	(1)	(2)	(2)
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	7
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	7
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	1	1	1
Interest cost	11	12	13
Expected return on plan assets	(21)	(22)	(22)
Amortization of:
Prior service cost (credit)	5	5	5
Actuarial (gain) loss	9	7	9
Net periodic defined benefit costs (credits)	$ 5	$ 3	$ 6
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	$ (2)	$ (3)	$ (4)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss	(19)	22	(9)
Prior service costs (credit)	0	0	7
Amortization of: [Abstract]
Prior service (cost) credit	(5)	(5)	(5)
Actuarial gain (loss)	(9)	(7)	(9)
Total recognized in OCI and regulatory assets/liabilities	(33)	10	(16)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(28)	13	(10)
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	(16)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ 3	$ 4	$ 8
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	$ (2)	$ (3)	$ (4)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements	5	6	5
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	$ 5
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member]
Amortization of:
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ (2)	$ (3)	$ (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	$ 2	$ 2	$ 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	$ (2)	$ (3)	$ (4)
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	$ 3
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)	$ (2)	$ (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)	$ 2	$ 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	$ (1)	$ (2)	$ (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)	$ (2)	$ (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	$ 1	$ 1
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ (1)	$ (2)	$ (2)

Retirement and Postemployment_4

Retirement and Postemployment Benefits (Weighted-Average Assumptions, Cost Trend Rates and Funded Status) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	$ 464	$ 535
Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	3.64%	4.35%
Benefit obligations valuation rate of compensation increase	3.79%	3.79%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost	4.35%	3.70%	4.21%
Net periodic benefit costs discount rate - interest cost	4.35%	3.70%	4.21%
Net periodic benefit costs rate of compensation increase	3.79%	3.78%	3.95%
Net periodic benefit costs expected return on plan assets	7.25%	7.25%	7.00%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	6.60%	6.60%	6.60%
Health care cost trend rate assumed for next year, cost	6.60%	6.60%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), obligations	5.00%	5.00%	5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), cost	5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate, obligations	2024	2023	2022
Year that the rate reaches the ultimate trend rate, cost	2023	2022	2022
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 3,883	$ 4,288
Service cost	50	62	$ 65
Interest cost	164	156	168
Participant contributions	0	0
Plan Amendments	2	1
Actuarial (gain) loss	368	(352)
Settlements	(21)	0
Gross benefits paid	(300)	(272)
Federal subsidy	0	0
Currency conversion	0	0
Benefit Obligation, end of period	4,146	3,883	4,288
Change in Plan Assets [Roll Forward]
Balance at beginning of period	3,109	3,488
Actual return on plan assets	735	(260)
Employer contributions	63	153
Participant contributions	0	0
Transfer out	0	0
Settlements	(22)	0
Gross benefits paid	(300)	(272)
Currency conversion	0	0
Balance at end of period	3,585	3,109	$ 3,488
Funded Status, end of period	(561)	(774)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	24	0
Current liability	(8)	(13)
Noncurrent liability	(577)	(761)
Net amount recognized, end of period	(561)	(774)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	34	40
Net actuarial (gain) loss	1,029	1,207
Total	1,063	1,247
Total accumulated benefit obligation for defined benefit pension plans	3,910	3,668
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	352	370
Regulatory assets/liabilities	711	877
Total	1,063	1,247
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	3,861	3,883
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	3,275	3,109
Accumulated benefit obligation	3,624	3,668
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 3,275	$ 3,109
Pension Plan [Member] | U.K. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	1.94%	2.98%
Benefit obligations valuation rate of compensation increase	3.25%	3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost	3.12%	2.73%	2.99%
Net periodic benefit costs discount rate - interest cost	2.62%	2.31%	2.41%
Net periodic benefit costs rate of compensation increase	3.50%	3.50%	3.50%
Net periodic benefit costs expected return on plan assets	7.21%	7.23%	7.22%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 7,275	$ 8,219
Service cost	68	82	$ 76
Interest cost	187	185	178
Participant contributions	12	13
Plan Amendments	0	12
Actuarial (gain) loss	1,220	(406)
Settlements	0	0
Gross benefits paid	(363)	(381)
Federal subsidy	0	0
Currency conversion	116	(449)
Benefit Obligation, end of period	8,515	7,275	8,219
Change in Plan Assets [Roll Forward]
Balance at beginning of period	7,801	8,490
Actual return on plan assets	1,095	(30)
Employer contributions	278	188
Participant contributions	12	13
Transfer out	0	0
Settlements	0	0
Gross benefits paid	(363)	(381)
Currency conversion	122	(479)
Balance at end of period	8,945	7,801	$ 8,490
Funded Status, end of period	430	526
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	440	535
Current liability	(1)	(1)
Noncurrent liability	(9)	(8)
Net amount recognized, end of period	430	526
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	11	12
Net actuarial (gain) loss	3,435	2,806
Total	3,446	2,818
Total accumulated benefit obligation for defined benefit pension plans	7,821	6,689
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total	3,446	2,818
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	10	9
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	0	0
Accumulated benefit obligation	10	9
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 0	$ 0
Other Postretirement Benefits Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	3.60%	4.31%
Benefit obligations valuation rate of compensation increase	3.76%	3.76%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost	4.31%	3.64%	4.11%
Net periodic benefit costs discount rate - interest cost	4.31%	3.64%	4.11%
Net periodic benefit costs rate of compensation increase	3.76%	3.75%	3.92%
Net periodic benefit costs expected return on plan assets	6.46%	6.40%	6.21%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 538	$ 589
Service cost	6	7	$ 7
Interest cost	22	21	23
Participant contributions	14	13
Plan Amendments	0	0
Actuarial (gain) loss	34	(34)
Settlements	0	0
Gross benefits paid	(58)	(58)
Federal subsidy	1	0
Currency conversion	0	0
Benefit Obligation, end of period	557	538	589
Change in Plan Assets [Roll Forward]
Balance at beginning of period	301	405
Actual return on plan assets	71	(20)
Employer contributions	10	23
Participant contributions	10	11
Transfer out	0	(65)
Settlements	0	0
Gross benefits paid	(52)	(53)
Currency conversion	0	0
Balance at end of period	340	301	$ 405
Funded Status, end of period	(217)	(237)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	11	2
Current liability	(2)	(3)
Noncurrent liability	(226)	(236)
Net amount recognized, end of period	(217)	(237)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	10	10
Net actuarial (gain) loss	6	24
Total	16	34
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	13	21
Regulatory assets/liabilities	3	13
Total	16	34
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	179	285
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	$ 122	$ 120
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	3.62%	4.35%
Benefit obligations valuation rate of compensation increase	3.50%	3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	4.35%	3.69%	4.19%
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%	7.00%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	6.60%	6.60%	6.60%
Health care cost trend rate assumed for next year, cost	6.60%	6.60%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), obligations	5.00%	5.00%	5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), cost	5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate, obligations	2024	2023	2022
Year that the rate reaches the ultimate trend rate, cost	2023	2022	2022
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 1,580	$ 1,771
Service cost	22	25	$ 24
Interest cost	66	63	68
Participant contributions	0	0
Plan Amendments	2	0
Actuarial (gain) loss	166	(168)
Settlements	(16)	0
Gross benefits paid	(136)	(111)
Benefit Obligation, end of period	1,684	1,580	1,771
Defined Benefit Plan One Time Cash Payouts To Terminated Vested Employees	74	52
Change in Plan Assets [Roll Forward]
Balance at beginning of period	1,294	1,402
Actual return on plan assets	304	(106)
Employer contributions	24	109
Participant contributions	0	0
Settlements	(16)	0
Gross benefits paid	(136)	(111)
Balance at end of period	1,470	1,294	$ 1,402
Funded Status, end of period	(214)	(286)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	24	0
Current liability	(5)	(4)
Noncurrent liability	(233)	(282)
Net amount recognized, end of period	(214)	(286)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	30	35
Net actuarial (gain) loss	380	439
Total	410	474
Total accumulated benefit obligation for defined benefit pension plans	1,561	1,467
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	132	118
Regulatory assets/liabilities	278	356
Total	410	474
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	1,398	1,580
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	1,160	1,294
Accumulated benefit obligation	1,276	1,467
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 1,160	$ 1,294
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	3.59%	4.32%
Benefit obligations valuation rate of compensation increase	3.50%	3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	4.32%	3.65%	4.12%
Net periodic benefit costs rate of compensation increase	3.50%	3.50%	3.50%
Net periodic benefit costs expected return on plan assets	7.00%	7.15%	6.82%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 205	$ 223
Service cost	4	4	$ 4
Interest cost	8	8	9
Participant contributions	7	8
Plan Amendments	0	0
Actuarial (gain) loss	5	(16)
Settlements	0	0
Gross benefits paid	(21)	(22)
Benefit Obligation, end of period	208	205	223
Change in Plan Assets [Roll Forward]
Balance at beginning of period	117	116
Actual return on plan assets	27	(9)
Employer contributions	11	24
Participant contributions	7	8
Settlements	0	0
Gross benefits paid	(21)	(22)
Balance at end of period	141	117	$ 116
Funded Status, end of period	(67)	(88)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	11	2
Current liability	(2)	(3)
Noncurrent liability	(76)	(87)
Net amount recognized, end of period	(67)	(88)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	10	12
Net actuarial (gain) loss	(37)	(25)
Total	(27)	(13)
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	4	10
Regulatory assets/liabilities	(31)	(23)
Total	$ (27)	$ (13)
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	3.60%	4.33%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	4.33%	3.65%	4.13%
Net periodic benefit costs expected return on plan assets	7.25%	7.25%	7.00%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 285	$ 326
Service cost	1	1	$ 1
Interest cost	11	12	13
Actuarial (gain) loss	25	(24)
Gross benefits paid	(36)	(30)
Benefit Obligation, end of period	286	285	326
Defined Benefit Plan One Time Cash Payouts To Terminated Vested Employees	21	16
Change in Plan Assets [Roll Forward]
Balance at beginning of period	281	325
Actual return on plan assets	64	(24)
Employer contributions	1	10
Gross benefits paid	(36)	(30)
Balance at end of period	310	281	$ 325
Funded Status, end of period	24	(4)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	24
Noncurrent liability		(4)
Net amount recognized, end of period	24	(4)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	17	22
Net actuarial (gain) loss	79	107
Total	96	129
Total accumulated benefit obligation for defined benefit pension plans	286	285
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total	96	129
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	(7)	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	63	65
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	(31)	1
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	$ 25

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, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2018
Pension Plan [Member] | U.S. [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,585	$ 3,585	$ 3,488	$ 3,585	$ 3,109
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,585	3,109	3,488
Balance at end of period		3,585	3,109
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 63	153
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				9
Estimated Future Benefit Payments (Details) [Abstract]
2020				271
2021				267
2022				266
2023				264
2024				265
2025-2029				$ 1,278
Pension Plan [Member] | U.S. [Member] | Subsequent Event [Member]
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	52
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				$ 63
Number Of Days Notice Required To Redeem Shares		45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	3,585	$ 3,109	3,109	3,585	$ 3,109
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,585	3,109
Balance at end of period		3,585	3,109
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	685	591	591	685	591
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	685	591
Balance at end of period		685	591
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	949	924	924	949	924
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	949	924
Balance at end of period		949	924
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	24	46	46	24	46
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	24	46	37
Actual return on plan assets relating to assets still held at the reporting date		3	(1)
Actual return on plan assets relating to assets sold during the period		3	3
Purchases, sales and settlements		(28)	7
Balance at end of period		24	46
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				182	220
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				182	220
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				451	340
Measured at fair value not using net asset value per share				194	159
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				194	159
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				554	466
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				621	543
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				310	212
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				309	212
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	0
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				951	899
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				931	874
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				20	25
Fair value at end of period	20	20	13	20	25
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20	25	13
Actual return on plan assets relating to assets still held at the reporting date		(1)	(2)
Actual return on plan assets relating to assets sold during the period		3	3
Purchases, sales and settlements		(7)	11
Balance at end of period		20	25
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				14	17
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				14	17
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				88	90
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	3,628	3,240	3,240	3,628	3,240
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,628	3,240
Balance at end of period		3,628	3,240
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				62	65
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				194	175
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				3	33
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				3	33
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				4	21
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				4	21
Fair value at end of period	4	21	21	4	21
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4	21	24
Actual return on plan assets relating to assets still held at the reporting date		4	1
Actual return on plan assets relating to assets sold during the period		0	0
Purchases, sales and settlements		(21)	(4)
Balance at end of period		4	21
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	99	(2)	(2)	99	(2)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	99	(2)
Balance at end of period		99	(2)
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	(142)	(129)	(129)	$ (142)	$ (129)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(142)	(129)
Balance at end of period		(142)	(129)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				57.00%	55.00%
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%	30.00%
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				14.00%	15.00%
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%	10.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				42.00%	43.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				43.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				35.00%	39.00%
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				7.00%	4.00%
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%	2.00%
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	8,945	7,801	7,801	$ 8,945	$ 7,801
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	8,945	7,801	8,490
Balance at end of period		8,945	7,801
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 278	188
Amount to be contributed to plan in the next fiscal year				273
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]
2020				353
2021				351
2022				356
2023				359
2024				364
2025-2029				1,826
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	154	$ 147	147	154	147
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	154	147
Balance at end of period		154	147
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	3,824	2,937	2,937	3,824	2,937
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,824	2,937
Balance at end of period		3,824	2,937
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
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
Pension Plan [Member] | U.K. [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				2.00%	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				$ 154	$ 147
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				154	147
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				$ 22	$ 27
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%	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				$ 54	$ 76
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%	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				$ 35	$ 49
Pension Plan [Member] | U.K. [Member] | North American Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				1.00%	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				$ 74	$ 105
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%	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				$ 32	$ 44
Pension Plan [Member] | U.K. [Member] | Global Equities Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				19.00%	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				$ 1,684	$ 1,465
Pension Plan [Member] | U.K. [Member] | Global Tactical Asset Allocation Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				29.00%	31.00%
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				$ 2,584	$ 2,437
Pension Plan [Member] | U.K. [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				43.00%	38.00%
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 not using net asset value per share				$ 5	$ 4
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 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 not using net asset value per share				5	4
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 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				3,819	2,933
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				3,819	2,933
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				6.00%	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				$ 519	$ 485
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	8,982	7,772	7,772	8,982	7,772
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	8,982	7,772
Balance at end of period		8,982	7,772
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	(37)	29	29	$ (37)	$ 29
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(37)	29
Balance at end of period		(37)	29
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	340	301	301	$ 340	$ 301
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	340	301	405
Balance at end of period		340	301
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		10	23
Amount to be contributed to plan in the next fiscal year				14
Estimated Future Benefit Payments (Details) [Abstract]
2020				50
2021				48
2022				47
2023				46
2024				44
2025-2029				200
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2020				1
Federal subsidy 2021				1
Federal subsidy 2022				0
Federal subsidy 2023				0
Federal subsidy 2024				0
Federal subsidy 2025-2029				1
Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	6	6	6	6	6
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	6	6
Balance at end of period		6	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	35	28	28	35	28
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	35	28
Balance at end of period		35	28
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
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
Other Postretirement Benefits Plan [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				3.00%	4.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				5.00%
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member]
Assumptions Used in Calculations (Numeric) [Abstract]
Number of months from date of purchase that investment must mature		13 months
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				$ 6	$ 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				6	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				45.00%	40.00%
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	$ 69
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				$ 68	$ 68
Other Postretirement Benefits Plan [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				52.00%	56.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				50.00%
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				$ 35	$ 28
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				35	28
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	198	$ 171	171	198	171
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	198	171
Balance at end of period		198	171
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	0	1	1	0	1
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0	1
Balance at end of period		0	1
Other Postretirement Benefits Plan [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	142	129	129	142	129
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	142	129
Balance at end of period		142	129
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	1,470	1,470	1,402	1,470	$ 1,294
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,470	1,294	1,402
Balance at end of period		1,470	1,294
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 24	$ 109
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				5
Estimated Future Benefit Payments (Details) [Abstract]
2020				114
2021				115
2022				115
2023				113
2024				115
2025-2029				$ 545
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Subsequent Event [Member]
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	22
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				$ 1,500	$ 1,300
Undivided interest percentage in each asset category that PPL subsidiary holds		41.00%	42.00%
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				63
Number Of Days Notice Required To Redeem Shares		45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	3,585	$ 3,585	$ 3,109	3,585	3,109
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,585	3,109
Balance at end of period		3,585	3,109
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	685	685	591	685	591
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	685	591
Balance at end of period		685	591
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	949	949	924	949	924
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	949	924
Balance at end of period		949	924
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	24	24	46	24	46
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	24	46	37
Actual return on plan assets relating to assets still held at the reporting date		3	(1)
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		(28)	7
Balance at end of period		24	46
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				182	220
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				182	220
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				451	340
Measured at fair value not using net asset value per share				194	159
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				194	159
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				554	466
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				621	543
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				310	212
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				309	212
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	0
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				951	899
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				931	874
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				20	25
Fair value at end of period	20	20	25	20	25
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20	25	13
Actual return on plan assets relating to assets still held at the reporting date		(1)	(2)
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		(7)	11
Balance at end of period		20	25
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				14	17
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				14	17
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				88	90
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	3,628	3,628	3,240	3,628	3,240
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,628	3,240
Balance at end of period		3,628	3,240
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				62	65
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				194	175
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				3	33
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				3	33
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				4	21
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				4	21
Fair value at end of period	4	4	21	4	21
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4	21	24
Actual return on plan assets relating to assets still held at the reporting date		4	1
Actual return on plan assets relating to assets sold during the period		0
Purchases, sales and settlements		(21)	(4)
Balance at end of period		4	21
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	99	99	(2)	99	(2)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	99	(2)
Balance at end of period		99	(2)
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	(142)	(142)	(129)	$ (142)	$ (129)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(142)	(129)
Balance at end of period		(142)	(129)
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				57.00%	55.00%
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%	30.00%
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				14.00%	15.00%
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%	10.00%
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				42.00%	43.00%
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				35.00%	39.00%
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				7.00%	4.00%
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%	2.00%
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	141	141	116	$ 141	$ 117
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	141	117	116
Balance at end of period		141	117
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		11	24
Amount to be contributed to plan in the next fiscal year				14
Estimated Future Benefit Payments (Details) [Abstract]
2020				14
2021				15
2022				15
2023				15
2024				15
2025-2029				72
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2020				1
Federal subsidy 2021				0
Federal subsidy 2022				0
Federal subsidy 2023				0
Federal subsidy 2024				0
Federal subsidy 2025-2029				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	281	281	$ 310	$ 281
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	310	281	325
Balance at end of period		310	281
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 1	$ 10
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	$ 281
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				63
Number Of Days Notice Required To Redeem Shares		45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	3,585	$ 3,585	$ 3,109	3,585	3,109
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,585	3,109
Balance at end of period		3,585	3,109
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	685	685	591	685	591
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	685	591
Balance at end of period		685	591
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	949	949	924	949	924
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	949	924
Balance at end of period		949	924
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	24	24	46	24	46
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	24	46	37
Actual return on plan assets relating to assets still held at the reporting date		3	(1)
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		(28)	7
Balance at end of period		24	46
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				182	220
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				182	220
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				451	340
Measured at fair value not using net asset value per share				194	159
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				194	159
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				554	466
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				621	543
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				310	212
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				309	212
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	0
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				951	899
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				931	874
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				20	25
Fair value at end of period	20	20	25	20	25
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20	25	13
Actual return on plan assets relating to assets still held at the reporting date		(1)	(2)
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		(7)	11
Balance at end of period		20	25
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				14	17
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				14	17
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				88	90
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	3,628	3,628	3,240	3,628	3,240
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,628	3,240
Balance at end of period		3,628	3,240
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				62	65
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				194	175
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				3	33
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				3	33
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				4	21
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				4	21
Fair value at end of period	4	4	21	4	21
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4	21	24
Actual return on plan assets relating to assets still held at the reporting date		4	1
Actual return on plan assets relating to assets sold during the period		0
Purchases, sales and settlements		(21)	(4)
Balance at end of period		4	21
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	99	99	(2)	99	(2)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	99	(2)
Balance at end of period		99	(2)
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	(142)	(142)	(129)	$ (142)	$ (129)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	$ (142)	(129)
Balance at end of period		$ (142)	$ (129)
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				57.00%	55.00%
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%	30.00%
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				14.00%	15.00%
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%	10.00%
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				42.00%	43.00%
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				35.00%	39.00%
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				7.00%	4.00%
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%	2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				2.00%

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, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 42	$ 40	$ 36
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	21	20	18
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	6	6	5
Kentucky Utilities Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 5	$ 5	$ 4

Jointly Owned Facilities (Detai

Jointly Owned Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 440	$ 427
Accumulated depreciation	54	77
Construction work in progress	$ 2	$ 0
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,278	$ 1,063
Accumulated depreciation	203	199
Construction work in progress	$ 134	$ 293
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	$ 427
Accumulated depreciation	54	77
Construction work in progress	$ 2	$ 0
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	$ 1,278	$ 1,063
Accumulated depreciation	203	199
Construction work in progress	$ 134	$ 293
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	$ 45	$ 41
Accumulated depreciation	20	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	$ 52	$ 51
Accumulated depreciation	20	17
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	$ 427
Accumulated depreciation	54	77
Construction work in progress	$ 2	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	14.25%	14.25%
Electric plant	$ 340	$ 226
Accumulated depreciation	43	39
Construction work in progress	$ 69	$ 152
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	$ 32	$ 32
Accumulated depreciation	12	11
Construction work in progress	$ 0	$ 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	$ 78	$ 77
Accumulated depreciation	27	24
Construction work in progress	$ 0	$ 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	$ 119	$ 119
Accumulated depreciation	13	9
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	1
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%
Electric plant	$ 1
Accumulated depreciation	0
Construction work in progress	$ 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	$ 75	$ 66
Accumulated depreciation	32	31
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	$ 46	$ 46
Accumulated depreciation	14	15
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	$ 938	$ 837
Accumulated depreciation	160	160
Construction work in progress	$ 65	$ 141
Kentucky Utilities Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	71.00%	71.00%
Electric plant	$ 76	$ 76
Accumulated depreciation	29	25
Construction work in progress	$ 0	$ 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	$ 128	$ 129
Accumulated depreciation	46	41
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	78.00%	78.00%
Electric plant	$ 429	$ 428
Accumulated depreciation	49	36
Construction work in progress	$ 1	$ 0
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	2	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%
Electric plant	$ 2
Accumulated depreciation	0
Construction work in progress	$ 0

Commitments and Contingencies_2

Commitments and Contingencies (Energy Purchases, Energy Sales, Other Commitments and Legal Matters) (Details) $ in Millions	Nov. 30, 2014USD ($)	Jun. 30, 2017mi	Jul. 31, 2014claim	Dec. 31, 2013resident	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Jun. 01, 2015
Claim By Former Affiliate [Abstract]
Restructuring And Related Activities Ownership Percentage By Riverstone								35.00%
Amount Of Alleged Improper Distribution	$ 733
LKE [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2020					$ 31
2021					31
2022					31
2023					31
2024					31
Thereafter					399
Total					554
Purchases					22	$ 20	$ 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]
2020					31
2021					31
2022					31
2023					31
2024					31
Thereafter					399
Total					554
Purchases					22	20	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]
2020					21
2021					21
2022					21
2023					21
2024					22
Thereafter					276
Total					382
Purchases					15	14	14
Kentucky Utilities Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2020					10
2021					10
2022					10
2023					10
2024					9
Thereafter					123
Total					172
Purchases					7	6	$ 6
PPL Electric Additional Sites [Member] | PPL Electric [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies					10	11
PPL Electric Additional Sites [Member] | PPL Electric Utilities Corp [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies					$ 10	$ 11

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Matter and Other) (Details) - PPL Electric Additional Sites [Member] - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
PPL Electric [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	$ 10	$ 11
PPL Electric Utilities Corp [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	$ 10	$ 11

Commitments and Contingencies_4

Commitments and Contingencies (Guarantees and Other Assurances) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)Integer	Dec. 31, 2018USD ($)
Guarantor Obligations [Line Items]
Recorded liability for all guarantees	$ 5	$ 6
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage	$ 225
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications Related To WPD Midlands Acquisition [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable	The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.
PPL Guarantee [Member] | Indemnification Guarantee [Member] | WPD Indemnifications For Entities In Liquidation Sales Of Assets [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 10
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	$ 83
PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	26
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)	P12Y
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
PPL Electric Utilities Corp [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	26
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)	P12Y
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	110
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	76
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	$ 34
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	$ 110

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 59	$ 59	$ 182
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	32
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Accounts receivable from affiliates [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	10
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Other Noncurrent Assets [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	22
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	152	148	64
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	150	113
Interest Expense, Related Party	31	25	18
Long-term debt to affiliate	650	650
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	28	26	20
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	$ 150	$ 113
Intercompany borrowings demand note rate on outstanding borrowing	3.20%	3.85%
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	3.50%
Interest Expense, Related Party	$ 14
Long-term debt to affiliate	$ 400
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member] | Note Payable 1 [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing	4.00%
Interest Expense, Related Party	$ 10	$ 7
Long-term debt to affiliate	$ 250
LG And E And KU Energy LLC [Member] | Company Affiliate1 [Member]
Intercompany Borrowings (Numeric) [Abstract]
Debt Instrument, Term	10 years
Interest Expense, Related Party		14	14
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]
Notes payable to affiliates	0	0
Intercompany Money Pool Agreement Maximum Borrowing Capacity	500
Louisville Gas And Electric Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	160	151	169
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	0	0
Intercompany Money Pool Agreement Maximum Borrowing Capacity	500
Kentucky Utilities Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 178	$ 169	$ 190

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Other Income [Line Items]
Economic foreign currency exchange contracts	$ (14)	$ 150	$ (261)
Defined benefit plans - non-service credits	316	257	167
Interest income	16	6	2
Allowance for funds used during construction - equity component	23	21	16
Miscellaneous	7	6	17
Total Other Income	348	440	(59)
Other Expense [Line Items]
Charitable contributions	17	24	8
Miscellaneous	22	20	21
Total Other Expense	39	44	29
Other Income (Expense) - net	309	396	(88)
PPL Electric Utilities Corp [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	4	5	1
Interest income	2	2	1
Allowance for funds used during construction - equity component	23	20	15
Total Other Income	29	27	17
Other Expense [Line Items]
Charitable contributions	3	3	2
Miscellaneous	1	1	3
Total Other Expense	4	4	5
Other Income (Expense) - net	$ 25	$ 23	$ 12

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Assets
Cash and cash equivalents	$ 815	$ 621
Restricted cash and cash equivalents	21	22
Money market fund	0	59
Commingled debt fund measured at NAV	29	0
Commingled equity fund measured at NAV	27	0
Total special use funds	56	59
Price risk management assets:
Foreign currency contracts	142	202
Cross-currency swaps	154	135
Total price risk management assets	296	337
Total Assets	1,188	1,039
Price risk management liabilities:
Interest rate swaps	21	20
Foreign currency contracts	5	2
Total price risk management liabilities	26	22
Level 1 [Member]
Assets
Cash and cash equivalents	815	621
Restricted cash and cash equivalents	21	22
Money market fund	0	59
Total special use funds	0	59
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total Assets	836	702
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
Money market fund	0	0
Total special use funds	0	0
Price risk management assets:
Foreign currency contracts	142	202
Cross-currency swaps	154	135
Total price risk management assets	296	337
Total Assets	296	337
Price risk management liabilities:
Interest rate swaps	21	20
Foreign currency contracts	5	2
Total price risk management liabilities	26	22
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Money market fund	0	0
Total special use funds	0	0
Price risk management assets:
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	262	267
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total Assets	264	269
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	262	267
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total Assets	264	269
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	27	24
Price risk management assets:
Total Assets	27	24
Price risk management liabilities:
Interest rate swaps	21	20
Total price risk management liabilities	21	20
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	27	24
Price risk management assets:
Total Assets	27	24
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	21	20
Total price risk management liabilities	21	20
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	15	10
Price risk management assets:
Total Assets	15	10
Price risk management liabilities:
Interest rate swaps	21	20
Total price risk management liabilities	21	20
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	15	10
Price risk management assets:
Total Assets	15	10
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	21	20
Total price risk management liabilities	21	20
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	12	14
Price risk management assets:
Total Assets	12	14
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	12	14
Price risk management assets:
Total Assets	12	14
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, 2019	Dec. 31, 2018
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 21,893	$ 20,599
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	25,481	22,939
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	3,985	3,694
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	4,589	3,901
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	6,002	5,502
LG And E And KU Energy LLC [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	6,766	5,768
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,005	1,809
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,278	1,874
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,623	2,321
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 3,003	$ 2,451

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 14	$ 40
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	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, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2019GBP (£)
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
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	1,300		£ 859
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	32	$ 31
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	147
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	147
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	$ 147

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities (Fair Values) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Derivatives Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 154	$ 135
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	6
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	5	6
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	149	129
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	149	129
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
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 Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [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	142	202
Liability value	26	22
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	142	103
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	142	103
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	99
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] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	99
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	9	6
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	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	5	2
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	16
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	16
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
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [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	21	20
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	4	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	4	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	17	16
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	17	16
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	21	20
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	4	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	4	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	17	16
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	$ 17	$ 16

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Derivative Instruments Gain Loss [Line Items]
Interest Expense	$ 994	$ 963	$ 901
Other Income (Expense) - net	309	396	(88)
Cash Flow Hedges [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(18)	35	(91)
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(13)	45	(98)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(30)	4	0
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
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(9)	(8)	(9)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(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	17	41	(98)
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	(9)	42	(82)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(9)
Hedged Items	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
Hedged Items	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	2	11	1
Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(19)	145	(267)
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	(1)	6	5
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)	(6)
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	(14)	150	(261)
LG And E And KU Energy LLC [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	226	206	197
Other Income (Expense) - net	(13)	(16)	(8)
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	(1)	6	5
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)	(6)
Louisville Gas And Electric Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	87	76	71
Other Income (Expense) - net	(11)	(12)	(10)
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	(1)	6	5
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)	(6)
Kentucky Utilities Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	109	100	96
Other Income (Expense) - net	$ (4)	$ (6)	$ (4)

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities (Offsetting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	$ 14	$ 40
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	3
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	3
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	296	337
Derivative instruments eligible for offset - assets	5	2
Cash collateral received eligible for offset - assets	14	40
Net assets	277	295
Gross liabilities	26	22
Derivative instruments eligible for offset - liabilities	5	2
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	21	20
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	0
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	3
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	3
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	21	20
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	21	20
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
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	3
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	3
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	21	20
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	21	20
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, 2019	Dec. 31, 2018
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	$ 3,162	$ 3,258
Effect of foreign currency exchange rates	34	(149)
Goodwill recognized during the period	0	53
Other	2	0
Balance at end of period	3,198	3,162
U.K. Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	2,447	2,596
Effect of foreign currency exchange rates	34	(149)
Goodwill recognized during the period	0	0
Other	2	0
Balance at end of period	2,483	2,447
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
Goodwill recognized during the period	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	0
Effect of foreign currency exchange rates	0	0
Goodwill recognized during the period	0	53
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, 2019	Dec. 31, 2018	Dec. 31, 2017
Subject to amortization: [Abstract]
Gross carrying amount	$ 598	$ 576
Accumulated amortization	222	204
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	367	345
Gross carrying amount - other intangible assets	965	921
Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	361	339
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	137
Accumulated amortization	84	75
Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	440	418
Accumulated amortization	135	128
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	22	21
Accumulated amortization	3	1
Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	9	7	$ 6
Forecasted amortization in 2019	9
Forecasted amortization in 2020	9
Forecasted amortization in 2021	9
Forecasted amortization in 2022	9
Forecasted amortization in 2023	9
Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	9	8	9
Forecasted amortization in 2019	8
Forecasted amortization in 2020	8
Forecasted amortization in 2021	8
Forecasted amortization in 2022	8
Forecasted amortization in 2023	8
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	18	15	15
Forecasted amortization in 2019	17
Forecasted amortization in 2020	17
Forecasted amortization in 2021	17
Forecasted amortization in 2022	17
Forecasted amortization in 2023	17
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount	373	365
Accumulated amortization	126	122
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets	390	382
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	370	363
Accumulated amortization	125	121
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	3	2
Accumulated amortization	1	1
LG And E And KU Energy LLC [Member]
Subject to amortization: [Abstract]
Gross carrying amount	147	147
Accumulated amortization	78	69
LG And E And KU Energy LLC [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	22	21
Accumulated amortization	4	3
LG And E And KU Energy LLC [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	125	126
Accumulated amortization	74	66
LG And E And KU Energy LLC [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	9	8	9
Forecasted amortization in 2019	8
Forecasted amortization in 2020	8
Forecasted amortization in 2021	8
Forecasted amortization in 2022	8
Forecasted amortization in 2023	8
Louisville Gas And Electric Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	93	94
Accumulated amortization	52	47
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	87
Accumulated amortization	51	46
Louisville Gas And Electric Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	6	6	6
Forecasted amortization in 2019	6
Forecasted amortization in 2020	6
Forecasted amortization in 2021	6
Forecasted amortization in 2022	6
Forecasted amortization in 2023	6
Kentucky Utilities Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	54	53
Accumulated amortization	26	22
Kentucky Utilities Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	15	14
Accumulated amortization	3	2
Kentucky Utilities Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	39	39
Accumulated amortization	23	20
Kentucky Utilities Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	3	$ 2	$ 3
Forecasted amortization in 2019	2
Forecasted amortization in 2020	2
Forecasted amortization in 2021	2
Forecasted amortization in 2022	2
Forecasted amortization in 2023	$ 2

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 347	$ 397
Accretion	19	20
Obligations incurred	0	8
Changes in estimated cash flow or settlement date	12	(3)
Effect of foreign currency exchange rates	0	(3)
Obligations settled	(96)	(72)
Balance at End of Period	282	347
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	296	356
Accretion	17	18
Obligations incurred	0	8
Changes in estimated cash flow or settlement date	(2)	(14)
Effect of foreign currency exchange rates	0	0
Obligations settled	(96)	(72)
Balance at End of Period	215	296
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	103	121
Accretion	6	6
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	(2)	(2)
Effect of foreign currency exchange rates	0	0
Obligations settled	(34)	(22)
Balance at End of Period	73	103
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	193	235
Accretion	11	12
Obligations incurred	0	8
Changes in estimated cash flow or settlement date	0	(12)
Effect of foreign currency exchange rates	0	0
Obligations settled	(62)	(50)
Balance at End of Period	$ 142	$ 193

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	$ (3,964)	$ (3,422)	$ (3,778)
Amounts arising during the year	(496)	(606)	151
Reclassifications from AOCI	102	115	205
Net OCI during the year	(394)	(491)	356
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(51)
Balance at end of year	(4,358)	(3,964)	(3,422)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(1,533)	(1,089)	(1,627)
Amounts arising during the year	108	(444)	538
Reclassifications from AOCI	0	0	0
Net OCI during the year	108	(444)	538
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		0
Balance at end of year	(1,425)	(1,533)	(1,089)
Qualifying Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(7)	(13)	(7)
Amounts arising during the year	(11)	36	(79)
Reclassifications from AOCI	13	(29)	73
Net OCI during the year	2	7	(6)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(1)
Balance at end of year	(5)	(7)	(13)
Equity Investees AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	0	(1)
Amounts arising during the year	0	0	0
Reclassifications from AOCI	0	0	1
Net OCI during the year	0	0	1
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		0
Balance at end of year	0	0	0
Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(19)	(7)	(8)
Amounts arising during the year	(1)	(11)	0
Reclassifications from AOCI	2	2	1
Net OCI during the year	1	(9)	1
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(3)
Balance at end of year	(18)	(19)	(7)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(2,405)	(2,313)	(2,135)
Amounts arising during the year	(592)	(187)	(308)
Reclassifications from AOCI	87	142	130
Net OCI during the year	(505)	(45)	(178)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(47)
Balance at end of year	(2,910)	(2,405)	(2,313)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(89)	(88)	(70)
Amounts arising during the year	(7)	7	(25)
Reclassifications from AOCI	3	10	7
Net OCI during the year	(4)	17	(18)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(18)
Balance at end of year	(93)	(89)	(88)
LG And E And KU Energy LLC [Member] | Equity Investees AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	0	(1)
Amounts arising during the year	0	0	0
Reclassifications from AOCI	0	0	1
Net OCI during the year	0	0	1
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		0
Balance at end of year	0	0	0
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)	(8)
Amounts arising during the year	(1)	0	(2)
Reclassifications from AOCI	1	2	1
Net OCI during the year	0	2	(1)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(2)
Balance at end of year	(9)	(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	(80)	(79)	(61)
Amounts arising during the year	(6)	7	(23)
Reclassifications from AOCI	2	8	5
Net OCI during the year	(4)	15	(18)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment		(16)
Balance at end of year	$ (84)	$ (80)	$ (79)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Affected Line Item on the Statements of Income
Interest Expense	$ (994)	$ (963)	$ (901)
Other Income (Expense) - net	309	396	(88)
Total Pre-tax	2,155	2,285	1,912
Income Taxes	(409)	(458)	(784)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total After-Tax	(102)	(115)	(205)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(18)	35	(91)
Income Taxes	5	(6)	18
Total After-Tax	(13)	29	(73)
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	(9)	(8)	(9)
Qualifying Derivatives [Member] | Cross Currency Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Interest Expense	0	1	0
Other Income (Expense) - net	(9)	42	(82)
Equity Investees AOCI [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Other Income (Expense) - net	0	0	(1)
Total Pre-tax	0	0	(1)
Income Taxes	0	0	0
Total After-Tax	0	0	(1)
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(112)	(180)	(169)
Income Taxes	23	36	38
Total After-Tax	(89)	(144)	(131)
Defined Benefit Plans [Member] | Prior Service Costs [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(3)	(2)	(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	$ (109)	$ (178)	$ (167)

SCHEDULE I - CONDENSED UNCONS_2

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Revenues [Abstract]
Operating Revenues	$ 1,954	$ 1,933	$ 1,803	$ 2,079	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 7,769	$ 7,785	$ 7,447
Operating Expenses [Abstract]
Other operation and maintenance									1,985	1,983	1,802
Total Operating Expenses									4,929	4,933	4,546
Operating Loss	693	726	640	781	657	686	658	851	2,840	2,852	2,901
Other Income (Expense) - net [Abstract]
Other Income (Expense) - net									309	396	(88)
Interest Expense									994	963	901
Income Before Income Taxes									2,155	2,285	1,912
Income Taxes									409	458	784
Net income	$ 364	$ 475	$ 441	$ 466	$ 415	$ 445	$ 515	$ 452	1,746	1,827	1,128
Total other comprehensive income (loss)									(394)	(491)	356
Comprehensive Income Attributable to PPL Shareowners									$ 1,352	$ 1,336	$ 1,484
Net Income Available to PPL Corporation Common Shareowners: (in dollars per share)
Basic (in dollars per share)	$ 0.49	$ 0.66	$ 0.61	$ 0.65	$ 0.57	$ 0.63	$ 0.74	$ 0.65	$ 2.39	$ 2.59	$ 1.64
Diluted (in dollars per share)	$ 0.48	$ 0.65	$ 0.60	$ 0.64	$ 0.57	$ 0.62	$ 0.73	$ 0.65	$ 2.37	$ 2.58	$ 1.64
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic									728,512	704,439	685,240
Diluted									736,754	708,619	687,334
LG&E and KU Energy LLC Unconsolidated [Member]
Other Income (Expense) - net [Abstract]
Equity in earnings of subsidiaries									$ 477	$ 470	$ 397
Interest Income from Affiliate									28	25	14
Other Income (Expense) - net									505	495	411
Interest Expense									30	29	30
Interest Expense with Affiliates									32	28	20
Income Before Income Taxes									443	438	361
Income Taxes									(25)	(7)	45
Net income									468	445	316
Total other comprehensive income (loss)									(4)	17	(18)
Comprehensive Income Attributable to PPL Shareowners									$ 464	$ 462	$ 298

SCHEDULE I - CONDENSED UNCONS_3

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Flows from Operating Activities [Abstract]
Net cash provided by (used in) operating activities	$ 2,427	$ 2,821	$ 2,461
Cash Flows from Investing Activities [Abstract]
Net cash provided by (used in) investing activities	(3,080)	(3,361)	(3,161)
Cash Flows from Financing Activities [Abstract]
Issuance of equity, net of issuance costs	1,167	698	453
Net increase (decrease) in short-term debt	(278)	363	115
Retirement of long-term debt	(300)	(277)	(168)
Issuance of long-term debt	1,465	1,059	1,515
Payment of common stock dividends	(1,192)	(1,133)	(1,072)
Other	(26)	(20)	(19)
Net cash provided by (used in) financing activities	836	690	824
Cash and Cash Equivalents at Beginning of Period	621
Cash and Cash Equivalents at End of Period	815	621
LG&E and KU Energy LLC Unconsolidated [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	368	346	401
Cash Flows from Investing Activities [Abstract]
Capital contributions to affiliated subsidiaries	(93)	(128)	(30)
Net decrease (increase) in notes receivable from affiliates	(44)	(26)	(28)
Net cash provided by (used in) investing activities	(137)	(154)	(58)
Cash Flows from Financing Activities [Abstract]
Net increase (decrease) in notes payable to affiliates	14	110	58
Contributions from member	63	0	0
Distributions to member	(308)	(302)	(402)
Net cash provided by (used in) financing activities	(231)	(192)	(344)
Net Increase (Decrease) in Cash and Cash Equivalents	0	0	(1)
Cash and Cash Equivalents at Beginning of Period	0	0	1
Cash and Cash Equivalents at End of Period	0	0	0
Supplemental Disclosures of Cash Flow Information: [Abstract]
Cash Dividends Received from Subsidiaries	$ 411	$ 402	$ 418

SCHEDULE I - CONDENSED UNCONS_4

SCHEDULE I - CONDENSED UNCONSOLIDATED BALANCE SHEETS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current Assets
Cash and cash equivalents		$ 815	$ 621
Accounts Receivable [Abstract]
Other		105	107
Accounts receivable		687	663
Prepayments		79	70
Price risk management assets		147	109
Other current assets		98	63
Total Current Assets		2,767	2,432
Other Noncurrent Assets [Abstract]
Price risk management assets		149	228
Other noncurrent assets		386	192
Total Other Noncurrent Assets		6,431	6,506
Total Assets		45,680	43,396
Current Liabilities [Abstract]
Short-term debt		1,151	1,430
Long-term debt due within one year		1,172	530
Dividends		317	296
Taxes		99	110
Other current liabilities		535	551
Total Current Liabilities		4,900	4,563
Long-term Debt [Abstract]
Long-term Debt		20,721	20,069
Total Deferred Credits and Other Noncurrent Liabilities		7,068	7,107
Equity [Abstract]
Common stock	[1]	8	7
Additional paid-in capital		12,214	11,021
Earnings reinvested		5,127	4,593
Accumulated other comprehensive loss		(4,358)	(3,964)	$ (3,422)	$ (3,778)
Total Equity		12,991	11,657	10,761	9,899
Total Liabilities and Equity		$ 45,680	$ 43,396
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		767,233	720,323
Common stock shares outstanding		767,233	720,323
LG&E and KU Energy LLC Unconsolidated [Member]
Current Assets
Cash and cash equivalents		$ 0	$ 0	$ 0	$ 1
Accounts Receivable [Abstract]
Accounts receivable from affiliates		3	0
Income Taxes Receivable, Current		3	0
Notes receivable from affiliates		1,105	1,061
Total Current Assets		1,111	1,061
Investments [Abstract]
Affiliated companies at equity		5,577	5,422
Other Noncurrent Assets [Abstract]
Deferred income taxes		314	299
Total Assets		7,002	6,782
Current Liabilities [Abstract]
Notes payable to affiliates		150	177
Long-term debt due within one year		475	0
Accounts payable with affiliates		489	487
Taxes		0	11
Other current liabilities		6	6
Total Current Liabilities		1,120	681
Long-term Debt [Abstract]
Long-term debt		249	723
Notes payable to affiliates		691	650
Long-term Debt		940	1,373
Total Deferred Credits and Other Noncurrent Liabilities		0	5
Equity [Abstract]
Members Equity		4,942	4,723
Total Liabilities and Equity		$ 7,002	$ 6,782
[1]	1,560,000 shares authorized; 767,233 and 720,323 shares issued and outstanding at December 31, 2019 and December 31, 2018 .

SCHEDULE I - NOTES TO CONDENSED

SCHEDULE I - NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Condensed Unconsolidated Financial Statements [Line Items]
2020	$ 1,574
Aggregate maturities of long-term debt (Details) [Abstract]
2021	2,254
Principal outstanding	22,002	$ 20,694
Thereafter	14,799
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)	P12Y
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LG&E and KU Energy LLC Unconsolidated [Member] | Senior Unsecured Notes [Member]
Condensed Unconsolidated Financial Statements [Line Items]
2020	475
Aggregate maturities of long-term debt (Details) [Abstract]
2021	250
LG&E and KU Energy LLC Unconsolidated [Member] | Note Payable [Member] | PPL [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Principal outstanding	$ 650
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)	P12Y
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200

Quarterly Financial Data (Una_2

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended								12 Months Ended
	Nov. 30, 2019	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019		Dec. 31, 2018		Dec. 31, 2017
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 1,954	$ 1,933	$ 1,803	$ 2,079	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 7,769		$ 7,785		$ 7,447
Operating income		693	726	640	781	657	686	658	851	2,840		2,852		2,901
Net income		$ 364	$ 475	$ 441	$ 466	$ 415	$ 445	$ 515	$ 452	$ 1,746		$ 1,827		$ 1,128
Net income (loss) available to PPL common shareowners: [Abstract]
Basic (in dollars per share)		$ 0.49	$ 0.66	$ 0.61	$ 0.65	$ 0.57	$ 0.63	$ 0.74	$ 0.65	$ 2.39		$ 2.59		$ 1.64
Diluted (in dollars per share)		$ 0.48	$ 0.65	$ 0.60	$ 0.64	$ 0.57	$ 0.62	$ 0.73	$ 0.65	2.37		2.58		1.64
Dividends declared per share of common stock (in dollars per share)	$ 0.4125									$ 1.65		$ 1.64		$ 1.58
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 602	$ 590	$ 521	$ 645	$ 573	$ 548	$ 517	$ 639	$ 2,358		$ 2,277		$ 2,195
Operating income		193	193	161	198	155	178	133	228	745		694		700
Net income		$ 124	$ 118	$ 94	$ 121	$ 96	$ 111	$ 75	$ 148	$ 457	[1]	$ 430	[1]	$ 362	[1]
[1]	Net income equals comprehensive income.