Louisville Gas & Electric 10-K 14 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Jan. 31, 2019	Jun. 29, 2018
Document Entity Information [Line Items]
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Amendment Flag	false
Entity Registrant Name	PPL Corp
Entity Central Index Key	922,224
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Public Float			$ 19,960,102,687
Entity Common Stock, Shares Outstanding		720,936,897
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	PPL ELECTRIC UTILITIES CORP
Entity Central Index Key	317,187
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		66,368,056
LG And E And KU Energy LLC [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LG&E & KU Energy LLC
Entity Central Index Key	1,518,339
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LOUISVILLE GAS & ELECTRIC CO
Entity Central Index Key	60,549
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		21,294,223
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	KENTUCKY UTILITIES CO
Entity Central Index Key	55,387
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		37,817,878

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Revenues
Operating Revenues		$ 7,785	$ 7,447	$ 7,517
Operation
Fuel		799	759	791
Energy purchases		745	685	706
Other operation and maintenance		1,983	1,802	1,857
Depreciation		1,094	1,008	926
Taxes, other than income		312	292	301
Total Operating Expenses		4,933	4,546	4,581
Operating Income		2,852	2,901	2,936
Other Income (Expense) - net		396	(88)	502
Interest Expense		963	901	888
Income Before Income Taxes		2,285	1,912	2,550
Income Taxes		458	784	648
Net income		$ 1,827	$ 1,128	$ 1,902
Net Income Available to PPL Common Shareowners
Basic (in dollars per share)		$ 2.59	$ 1.64	$ 2.80
Diluted (in dollars per share)		$ 2.58	$ 1.64	$ 2.79
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		704,439	685,240	677,592
Diluted		708,619	687,334	680,446
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 2,277	$ 2,195	$ 2,156
Operation
Energy purchases		544	507	535
Other operation and maintenance		578	572	602
Depreciation		352	309	253
Taxes, other than income		109	107	105
Total Operating Expenses		1,583	1,495	1,495
Operating Income		694	700	661
Other Income (Expense) - net		23	12	20
Interest Income from Affiliate		8	5	0
Interest Expense		159	142	129
Income Before Income Taxes		566	575	552
Income Taxes		136	213	212
Net income	[1]	430	362	340
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		3,214	3,156	3,141
Operation
Fuel		799	759	791
Energy purchases		201	178	171
Other operation and maintenance		848	801	798
Depreciation		475	439	404
Taxes, other than income		70	65	62
Total Operating Expenses		2,393	2,242	2,226
Operating Income		821	914	915
Other Income (Expense) - net		(16)	(8)	(15)
Interest Expense		206	197	197
Interest Expense with Affiliates		25	18	17
Income Before Income Taxes		574	691	686
Income Taxes		129	375	257
Net income		445	316	429
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		1,467	1,422	1,406
Electric revenue from affiliates		29	31	24
Operating Revenues		1,496	1,453	1,430
Operation
Fuel		308	292	301
Energy purchases		183	160	153
Energy purchases from affiliate		13	10	14
Other operation and maintenance		376	350	350
Depreciation		195	183	170
Taxes, other than income		36	33	32
Total Operating Expenses		1,111	1,028	1,020
Operating Income		385	425	410
Other Income (Expense) - net		(12)	(10)	(10)
Interest Expense		76	71	71
Income Before Income Taxes		297	344	329
Income Taxes		64	131	126
Net income	[2]	233	213	203
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		1,747	1,734	1,735
Electric revenue from affiliates		13	10	14
Operating Revenues		1,760	1,744	1,749
Operation
Fuel		491	467	490
Energy purchases		18	18	18
Energy purchases from affiliate		29	31	24
Other operation and maintenance		441	423	422
Depreciation		279	255	234
Taxes, other than income		34	32	30
Total Operating Expenses		1,292	1,226	1,218
Operating Income		468	518	531
Other Income (Expense) - net		(6)	(4)	(7)
Interest Expense		100	96	96
Income Before Income Taxes		362	418	428
Income Taxes		76	159	163
Net income	[3]	$ 286	$ 259	$ 265
[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, 2018	Dec. 31, 2017	Dec. 31, 2016
Net income	$ 1,827	$ 1,128	$ 1,902
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	(444)	538	(1,107)
Qualifying derivatives, net of tax	36	(79)	91
Defined benefit plans:
Prior service costs, net of tax	(11)	0	(3)
Net actuarial gain (loss), net of tax	(187)	(308)	(61)
Reclassifications to net income - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	(29)	73	(91)
Equity investees' other comprehensive (income) loss, net of tax	0	1	(1)
Defined benefit plans:
Prior service costs, net of tax	2	1	1
Net actuarial (gain) loss, net of tax	142	130	121
Total other comprehensive income (loss)	(491)	356	(1,050)
Comprehensive income	1,336	1,484	852
LG And E And KU Energy LLC [Member]
Net income	445	316	429
Defined benefit plans:
Prior service costs, net of tax	0	(2)	0
Net actuarial gain (loss), net of tax	7	(23)	(27)
Reclassifications to net income - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax	0	1	(1)
Defined benefit plans:
Prior service costs, net of tax	2	1	2
Net actuarial (gain) loss, net of tax	8	5	2
Total other comprehensive income (loss)	17	(18)	(24)
Comprehensive income	$ 462	$ 298	$ 405

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Tax effect of foreign currency translation adjustments arising during the period	$ (2)	$ (1)	$ (4)
Tax effect of qualifying derivatives arising during the period	(9)	19	(18)
Tax effect of defined benefit plans - prior service costs arising during period	3	0	2
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	44	72	40
Tax effect of qualifying derivatives reclassified to net income	6	(18)	21
Tax effect of defined benefit plans - prior service costs reclassified to net income	0	(1)	(1)
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified to net income	(36)	(37)	(35)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - prior service costs arising during period	0	(1)	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	0	13	18
Tax effect of equity investees' other comprehensive (income) loss reclassified to net income	0	0	0
Tax effect of defined benefit plans - prior service costs reclassified to net income	0	1	1
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified to net income	$ 5	$ 2	$ 1

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flows from Operating Activities
Net income		$ 1,827	$ 1,128	$ 1,902
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		1,094	1,008	926
Amortization		78	97	80
Defined benefit plans - expense (income)		(192)	(95)	(40)
Deferred income taxes and investment tax credits		355	707	560
Unrealized (gains) losses on derivatives, and other hedging activities		(186)	178	19
Stock compensation expense		26	38	28
Other		(3)	(9)	(12)
Change in current assets and current liabilities
Accounts receivable		28	(33)	(15)
Accounts payable		78	(10)	57
Unbilled Revenues		41	(48)	(63)
Fuel, materials and supplies		17	40	(3)
Customer Deposits		(35)	16	(50)
Regulatory assets and liabilities, net		13	(12)	(59)
Other Current Liabilities		(22)	6	(6)
Other		33	(5)	55
Other operating activities
Defined benefit plans - funding		(361)	(565)	(427)
Proceeds from transfer of excess benefit plan funds		65	0	0
Other assets		(75)	32	33
Other liabilities		40	(12)	(95)
Net cash provided by operating activities		2,821	2,461	2,890
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(3,238)	(3,133)	(2,920)
Purchase of available-for-sale securities		(65)	0	0
Other investing activities		(58)	(28)	(6)
Net cash provided by (used in) investing activities		(3,361)	(3,161)	(2,926)
Cash Flows from Financing Activities
Issuance of long-term debt		1,059	1,515	1,342
Retirement of long-term debt		(277)	(168)	(930)
Issuance of common stock		698	453	144
Payment of common stock dividends		(1,133)	(1,072)	(1,030)
Net increase (decrease) in short-term debt		363	115	29
Other financing activities		(20)	(19)	6
Net cash provided by (used in) financing activities		690	824	(439)
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash		(18)	15	(28)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		132	139	(503)
Cash and Cash Equivalents at Beginning of Period		485
Cash and Cash Equivalents at End of Period		621	485
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		511	372	875
Cash, Cash Equivalents and Restricted Cash at End of Period		643	511	372
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		910	845	854
Income taxes - net		127	65	70
Accrued expenditures for property, plant and equipment at December 31,		345	360	281
Accrued expenditures for intangible assets at December 31,		64	68	117
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income	[1]	430	362	340
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		352	309	253
Amortization		22	33	32
Defined benefit plans - expense (income)		3	12	11
Deferred income taxes and investment tax credits		125	258	221
Other		(4)	(8)	(13)
Change in current assets and current liabilities
Accounts receivable		47	(57)	16
Accounts payable		10	3	58
Unbilled Revenues		7	(13)	(23)
Prepayments		1	3	43
Taxes payable		4	(4)	(12)
Regulatory assets and liabilities, net		(19)	(5)	(62)
Other		10	(1)	(7)
Other operating activities
Defined benefit plans - funding		(28)	(24)	0
Other assets		(37)	15	19
Other liabilities		55	(3)	(4)
Net cash provided by operating activities		978	880	872
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,192)	(1,244)	(1,125)
Expenditures for intangible assets		(4)	(10)	(9)
Other investing activities		3	2	4
Net cash provided by (used in) investing activities		(1,193)	(1,252)	(1,130)
Cash Flows from Financing Activities
Issuance of long-term debt		398	470	224
Retirement of long-term debt		0	0	(224)
Contributions from parent		429	575	220
Payment of common stock dividends to parent		(390)	(336)	(288)
Net increase (decrease) in short-term debt		0	(295)	295
Other financing activities		(4)	(6)	(3)
Net cash provided by (used in) financing activities		433	408	224
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		218	36	(34)
Cash and Cash Equivalents at Beginning of Period		49
Cash and Cash Equivalents at End of Period		267	49
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51	15	49
Cash, Cash Equivalents and Restricted Cash at End of Period		269	51	15
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		144	128	115
Income taxes - net		(20)	4	(48)
Accrued expenditures for property, plant and equipment at December 31,		158	133	126
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net income		445	316	429
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		475	439	404
Amortization		18	24	29
Defined benefit plans - expense (income)		17	25	27
Deferred income taxes and investment tax credits		94	294	291
Other		(4)	0	0
Change in current assets and current liabilities
Accounts receivable		1	(12)	(31)
Accounts payable		39	(9)	24
Unbilled Revenues		34	(33)	(23)
Accounts payable to affiliates		2	2	1
Fuel, materials and supplies		7	45	2
Taxes payable		(3)	27	(7)
Regulatory assets and liabilities, net		32	(7)	1
Other		(24)	41	(6)
Other operating activities
Defined benefit plans - funding		(131)	(35)	(85)
Settlement of interest rate swaps		0	0	(9)
Expenditures for asset retirement obligations		(72)	(34)	(26)
Other assets		(24)	8	2
Other liabilities		9	8	4
Net cash provided by operating activities		915	1,099	1,027
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,117)	(892)	(791)
Other investing activities		1	4	1
Net cash provided by (used in) investing activities		(1,116)	(888)	(790)
Cash Flows from Financing Activities
Issuance of long-term debt		118	160	221
Issuance of long-term note with affiliate		250	0	0
Retirement of long-term debt		(27)	(70)	(246)
Contributions from member		0	0	61
Distributions to member		(302)	(402)	(316)
Net increase (decrease) in notes payable to affiliates		(112)	62	109
Net increase (decrease) in short-term debt		270	59	(80)
Other financing activities		(2)	(3)	(3)
Net cash provided by (used in) financing activities		195	(194)	(254)
Net Increase (Decrease) in Cash and Cash Equivalents		(6)	17	(17)
Cash and Cash Equivalents at Beginning of Period		30	13	30
Cash and Cash Equivalents at End of Period		24	30	13
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		218	204	198
Income taxes - net		46	48	(24)
Accrued expenditures for property, plant and equipment at December 31,		150	174	104
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income	[2]	233	213	203
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		195	183	170
Amortization		14	14	14
Defined benefit plans - expense (income)		3	7	8
Deferred income taxes and investment tax credits		60	126	147
Other		0	1	0
Change in current assets and current liabilities
Accounts receivable		4	(7)	(22)
Accounts receivable from affiliates		0	4	(16)
Accounts payable		10	(7)	31
Unbilled Revenues		14	(16)	(8)
Accounts payable to affiliates		1	(4)	1
Fuel, materials and supplies		4	12	8
Taxes payable		1	(15)	20
Regulatory assets and liabilities, net		5	(5)	(1)
Other		(10)	16	(2)
Other operating activities
Defined benefit plans - funding		(61)	(4)	(46)
Settlement of interest rate swaps		0	0	(9)
Expenditures for asset retirement obligations		(22)	(15)	(18)
Other assets		(12)	5	0
Other liabilities		4	4	2
Net cash provided by operating activities		443	512	482
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(554)	(458)	(439)
Net cash provided by (used in) investing activities		(554)	(458)	(439)
Cash Flows from Financing Activities
Issuance of long-term debt		100	160	125
Retirement of long-term debt		0	(70)	(150)
Contributions from parent		83	30	71
Payment of common stock dividends to parent		(156)	(192)	(128)
Net increase (decrease) in short-term debt		80	30	27
Other financing activities		(1)	(2)	(2)
Net cash provided by (used in) financing activities		106	(44)	(57)
Net Increase (Decrease) in Cash and Cash Equivalents		(5)	10	(14)
Cash and Cash Equivalents at Beginning of Period		15	5	19
Cash and Cash Equivalents at End of Period		10	15	5
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		71	65	65
Income taxes - net		7	22	(43)
Accrued expenditures for property, plant and equipment at December 31,		61	92	56
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income	[3]	286	259	265
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		279	255	234
Amortization		3	9	14
Defined benefit plans - expense (income)		0	4	5
Deferred income taxes and investment tax credits		48	152	126
Other		(4)	0	(1)
Change in current assets and current liabilities
Accounts receivable		(4)	(5)	(8)
Accounts payable		29	0	(10)
Unbilled Revenues		20	(17)	(15)
Accounts payable to affiliates		(3)	(6)	15
Fuel, materials and supplies		3	32	(6)
Taxes payable		5	(26)	25
Regulatory assets and liabilities, net		27	(2)	2
Other		(3)	9	(4)
Other operating activities
Defined benefit plans - funding		(54)	(23)	(20)
Expenditures for asset retirement obligations		(50)	(19)	(8)
Other assets		(12)	3	(6)
Other liabilities		11	9	(2)
Net cash provided by operating activities		581	634	606
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(562)	(432)	(350)
Other investing activities		1	4	1
Net cash provided by (used in) investing activities		(561)	(428)	(349)
Cash Flows from Financing Activities
Issuance of long-term debt		18	0	96
Retirement of long-term debt		(27)	0	(96)
Contributions from parent		45	0	20
Payment of common stock dividends to parent		(246)	(226)	(248)
Net increase (decrease) in short-term debt		190	29	(32)
Other financing activities		(1)	(1)	(1)
Net cash provided by (used in) financing activities		(21)	(198)	(261)
Net Increase (Decrease) in Cash and Cash Equivalents		(1)	8	(4)
Cash and Cash Equivalents at Beginning of Period		15	7	11
Cash and Cash Equivalents at End of Period		14	15	7
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		95	92	89
Income taxes - net		25	34	13
Accrued expenditures for property, plant and equipment at December 31,		$ 88	$ 82	$ 47
[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, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents		$ 621	$ 485
Accounts receivable (less reserve:)
Customer		663	681
Other		107	100
Unbilled revenues		496	543
Fuel, materials and supplies		303	320
Prepayments		70	66
Price risk management assets		109	49
Regulatory assets		36	34
Other current assets		63	50
Total Current Assets		2,432	2,294
Property, Plant and Equipment
Regulated utility plant		39,734	38,228
Less: accumulated depreciation - regulated utility plant		7,310	6,785
Regulated utility plant, net		32,424	31,443
Non-regulated property, plant and equipment		355	384
Less: accumulated depreciation - non-regulated property, plant and equipment		101	110
Non-regulated property, plant and equipment, net		254	274
Construction work in progress		1,780	1,375
Property, Plant and Equipment, net		34,458	33,092
Other Noncurrent Assets
Regulatory assets		1,673	1,504
Goodwill		3,162	3,258
Other intangibles		716	697
Pension benefit asset		535	284
Price risk management assets		228	215
Other noncurrent assets		192	135
Total Other Noncurrent Assets		6,506	6,093
Total Assets		43,396	41,479
Current Liabilities
Short-term debt		1,430	1,080
Long-term debt due within one year		530	348
Accounts payable		989	924
Taxes		110	105
Interest		278	282
Dividends		296	273
Customer deposits		257	292
Regulatory liabilities		122	95
Other current liabilities		551	624
Total Current Liabilities		4,563	4,023
Long-term Debt [Abstract]
Long-term Debt		20,069	19,847
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		2,796	2,462
Investment tax credits		126	129
Accrued pension obligations		771	800
Asset retirement obligations		264	312
Regulatory liabilities		2,714	2,704
Other deferred credits and noncurrent liabilities		436	441
Total Deferred Credits and Other Noncurrent Liabilities		7,107	6,848
Equity
Common stock	[1]	7	7
Additional paid-in capital		11,021	10,305
Earnings reinvested		4,593	3,871
Accumulated other comprehensive loss		(3,964)	(3,422)
Total Equity		11,657	10,761
Total Liabilities and Equity		43,396	41,479
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		267	49
Accounts receivable (less reserve:)
Customer		264	279
Other		38	71
Accounts receivable from affiliates		11	0
Unbilled revenues		120	127
Fuel, materials and supplies		25	34
Prepayments		5	6
Regulatory assets		11	16
Other current assets		9	6
Total Current Assets		750	588
Property, Plant and Equipment
Regulated utility plant		11,637	10,785
Less: accumulated depreciation - regulated utility plant		2,856	2,778
Regulated utility plant, net		8,781	8,007
Construction work in progress		586	508
Property, Plant and Equipment, net		9,367	8,515
Other Noncurrent Assets
Regulatory assets		824	709
Other intangibles		260	259
Other noncurrent assets		42	11
Total Other Noncurrent Assets		1,126	979
Total Assets		11,243	10,082
Current Liabilities
Long-term debt due within one year		0	0
Accounts payable		418	386
Accounts payable to affiliates		25	31
Taxes		12	8
Interest		37	36
Regulatory liabilities		74	86
Other current liabilities		101	98
Total Current Liabilities		667	645
Long-term Debt [Abstract]
Long-term Debt		3,694	3,298
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,320	1,154
Accrued pension obligations		282	246
Regulatory liabilities		675	668
Other deferred credits and noncurrent liabilities		144	79
Total Deferred Credits and Other Noncurrent Liabilities		2,421	2,147
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		3,158	2,729
Earnings reinvested		939	899
Total Equity		4,461	3,992
Total Liabilities and Equity		11,243	10,082
LG And E And KU Energy LLC [Member]
Current Assets
Cash and cash equivalents		24	30
Accounts receivable (less reserve:)
Customer		239	246
Other		63	44
Unbilled revenues		169	203
Fuel, materials and supplies		248	254
Prepayments		25	25
Regulatory assets		25	18
Other current assets		0	8
Total Current Assets		793	828
Property, Plant and Equipment
Regulated utility plant		13,721	13,187
Less: accumulated depreciation - regulated utility plant		2,125	1,785
Regulated utility plant, net		11,596	11,402
Construction work in progress		1,018	627
Property, Plant and Equipment, net		12,614	12,029
Other Noncurrent Assets
Regulatory assets		849	795
Goodwill		996	996
Other intangibles		78	86
Other noncurrent assets		82	68
Total Other Noncurrent Assets		2,005	1,945
Total Assets		15,412	14,802
Current Liabilities
Short-term debt		514	244
Long-term debt due within one year		530	98
Notes payable with affiliates		113	225
Accounts payable		366	338
Accounts payable to affiliates		9	7
Taxes		63	66
Interest		32	32
Asset Retirement Obligations		82	85
Price risk management liabilities		4	4
Customer deposits		61	58
Regulatory liabilities		48	9
Other current liabilities		126	161
Total Current Liabilities		1,948	1,327
Long-term Debt [Abstract]
Long-term debt		4,322	4,661
Long-term debt to affiliate		650	400
Long-term Debt		4,972	5,061
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		956	866
Investment tax credits		126	129
Price risk management liabilities		16	22
Accrued pension obligations		282	365
Asset retirement obligations		214	271
Regulatory liabilities		2,039	2,036
Other deferred credits and noncurrent liabilities		136	162
Total Deferred Credits and Other Noncurrent Liabilities		3,769	3,851
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(89)	(88)
Member's Equity		4,723	4,563
Total Liabilities and Equity		15,412	14,802
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		10	15
Accounts receivable (less reserve:)
Customer		110	116
Other		30	13
Accounts receivable from affiliates		24	24
Unbilled revenues		77	91
Fuel, materials and supplies		127	131
Prepayments		12	11
Regulatory assets		21	12
Other current assets		0	3
Total Current Assets		411	416
Property, Plant and Equipment
Regulated utility plant		5,816	5,587
Less: accumulated depreciation - regulated utility plant		741	614
Regulated utility plant, net		5,075	4,973
Construction work in progress		514	305
Property, Plant and Equipment, net		5,589	5,278
Other Noncurrent Assets
Regulatory assets		431	411
Goodwill		389	389
Other intangibles		47	53
Other noncurrent assets		16	12
Total Other Noncurrent Assets		883	865
Total Assets		6,883	6,559
Current Liabilities
Short-term debt		279	199
Long-term debt due within one year		434	98
Accounts payable		172	179
Accounts payable to affiliates		26	23
Taxes		26	25
Interest		11	11
Asset Retirement Obligations		23	24
Price risk management liabilities		4	4
Customer deposits		29	27
Regulatory liabilities		17	3
Other current liabilities		39	52
Total Current Liabilities		1,060	645
Long-term Debt [Abstract]
Long-term Debt		1,375	1,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		628	572
Investment tax credits		34	35
Price risk management liabilities		16	22
Accrued pension obligations		11	45
Asset retirement obligations		80	97
Regulatory liabilities		915	919
Other deferred credits and noncurrent liabilities		77	86
Total Deferred Credits and Other Noncurrent Liabilities		1,761	1,776
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,795	1,712
Earnings reinvested		468	391
Total Equity		2,687	2,527
Total Liabilities and Equity		6,883	6,559
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		14	15
Accounts receivable (less reserve:)
Customer		129	130
Other		34	30
Unbilled revenues		92	112
Fuel, materials and supplies		121	123
Prepayments		11	14
Regulatory assets		4	6
Other current assets		0	5
Total Current Assets		405	435
Property, Plant and Equipment
Regulated utility plant		7,895	7,592
Less: accumulated depreciation - regulated utility plant		1,382	1,170
Regulated utility plant, net		6,513	6,422
Construction work in progress		503	321
Property, Plant and Equipment, net		7,016	6,743
Other Noncurrent Assets
Regulatory assets		418	384
Goodwill		607	607
Other intangibles		31	33
Other noncurrent assets		63	52
Total Other Noncurrent Assets		1,119	1,076
Total Assets		8,540	8,254
Current Liabilities
Short-term debt		235	45
Long-term debt due within one year		96	0
Accounts payable		171	137
Accounts payable to affiliates		53	53
Taxes		24	19
Interest		16	16
Asset Retirement Obligations		59	61
Customer deposits		32	31
Regulatory liabilities		31	6
Other current liabilities		35	46
Total Current Liabilities		752	414
Long-term Debt [Abstract]
Long-term Debt		2,225	2,328
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		735	691
Investment tax credits		92	94
Accrued pension obligations		1	36
Asset retirement obligations		134	174
Regulatory liabilities		1,124	1,117
Other deferred credits and noncurrent liabilities		35	43
Total Deferred Credits and Other Noncurrent Liabilities		2,121	2,155
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,661	2,616
Earnings reinvested		473	433
Total Equity		3,442	3,357
Total Liabilities and Equity		$ 8,540	$ 8,254
[1]	1,560,000 shares authorized; 720,323 and 693,398 shares issued and outstanding at December 31, 2018 and December 31, 2017.
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2018 and December 31, 2017
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2018 and December 31, 2017.
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2018 and December 31, 2017.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 56	$ 51
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	1,560,000	1,560,000
Common stock shares issued	720,323	693,398
Common stock shares outstanding	720,323	693,398
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 27	$ 24
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	$ 27	$ 25
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	$ 2	$ 1
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	80,000	80,000
Common stock shares issued	37,818	37,818
Common stock shares outstanding	37,818	37,818

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) shares in Thousands, $ in Millions		Total	Common Stock		Additional Paid-in Capital	Earnings Reinvested	Accumulated Other Comprehensive Loss	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member]Common Stock		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		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		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		$ 1.52
Balance at beginning of period - shares at Dec. 31, 2015			673,857	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2015														$ 4,517
Balance at beginning of period at Dec. 31, 2015		$ 9,919	$ 7		$ 9,687	$ 2,953	$ (2,728)	$ 3,119		$ 364		$ 1,934	$ 821		$ 2,330		$ 424		$ 1,611	$ 295	$ 3,287		$ 308		$ 2,596	$ 383	$ 0
Common stock shares issued	[1]		5,874
Common stock issued		185			185
Stock-based compensation		(31)			(31)
Net income		1,902				1,902		340	[5]				340	429	203	[6]				203	265	[7]				265
Capital contributions from parent								220				220			71				71		20				20
Dividends and dividend equivalents		(1,033)				(1,033)
Cash dividends declared on common stock								(288)					(288)		(128)					(128)	(248)					(248)
Contributions from member														61
Distributions to member														(316)
Other comprehensive income (loss)		(1,050)					(1,050)							(24)							(1)						(1)
Balance at end of period - shares at Dec. 31, 2016			679,731	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2016														4,667
Balance at end 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)
Cumulative Effect of New Accounting Principle in Period of Adoption		$ 7				(7)
Dividends Declared Per Share of Common Stock		$ 1.58
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	693,398	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		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)
[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, 2018vote	Dec. 31, 2017vote	Dec. 31, 2016USD ($)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, 2018
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 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 costs that are expected to be incurred in the future, 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 the uncertain future events and (2) the amount of the 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 that would 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 the 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 (PPL) Operating Revenues For the years ended December 31, the Statements of Income "Operating Revenues" line item contains revenue from the following: 2018 2017 2016 Domestic electric and gas revenues (a) $ 5,491 $ 5,351 $ 5,297 U.K. operating revenues (b) 2,268 2,091 2,207 Domestic - other 26 5 13 Total $ 7,785 $ 7,447 $ 7,517 (a) Represents revenues from cost-based rate-regulated generation, transmission and/or distribution in Pennsylvania, Kentucky and Virginia, including regulated wholesale revenue. (b) Primarily represents regulated electricity distribution revenues from the operation of WPD's distribution networks. Revenue Recognition (All Registrants) Operating revenues are primarily recorded based on energy deliveries through the end of the 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 rates in the future as a result of 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 an increase or reduction in 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 will allow future base demand revenues agreed with the regulator 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 they are billed to customers, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising for the periods beginning with the 2014/15 regulatory year and refunded/recovered under RIIO-ED1 are refunded/recovered on a two year lag (previously one year ). Therefore the 2015/16 over/under-recovery adjustment occurred in the 2017/18 regulatory year. 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 collectability 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 2018 $ 51 $ 41 $ 3 $ 39 $ 56 2017 54 28 (1 ) 30 51 2016 41 44 — 31 54 PPL Electric 2018 $ 24 $ 29 $ — $ 26 $ 27 2017 28 18 — 22 24 2016 16 35 — 23 28 LKE 2018 $ 25 $ 10 $ 3 $ 11 $ 27 2017 24 8 (1 ) 6 25 2016 23 8 — 7 24 LG&E 2018 $ 1 $ 4 $ 1 $ 5 $ 1 2017 2 2 (1 ) 2 1 2016 1 2 1 2 2 KU 2018 $ 1 $ 5 $ 2 $ 6 $ 2 2017 2 4 (1 ) 4 1 2016 2 4 — 4 2 (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." (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. (PPL) Investments in Debt Securities Investments in debt securities are classified as held-to-maturity and measured at amortized cost when there is an intent and ability to hold the securities to maturity. Debt securities held principally to capitalize on fluctuations in their value with the intention of selling them in the near-term are classified as trading. All other investments in debt securities are classified as available-for-sale. Both trading and available-for-sale securities are carried at fair value. The specific identification method is used to calculate realized gains and losses on debt securities. Unrealized gains and losses on available-for-sale debt securities are reported in other comprehensive income until realized. The criteria for determining whether a decline in fair value of a debt security is other than temporary and whether the other-than-temporary impairment is recognized in earnings or reported in OCI require that when a debt security is in an unrealized loss position and: • there is an intent or a requirement to sell the security before recovery, the other-than-temporary impairment is recognized currently in earnings; or • there is no intent or requirement to sell the security before recovery, the portion of the other-than-temporary impairment that is considered a credit loss is recognized currently in earnings and the remainder of the other-than-temporary impairment is reported in OCI, net of tax; or • there is no intent or requirement to sell the security before recovery and there is no credit loss, the unrealized loss is reported in OCI, net of tax. (PPL, LKE, LG&E and KU) Investments in Equity Securities LG&E and KU each have an investment in OVEC, which is recorded at cost. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU are responsible for a pro-rata share of certain OVEC obligations, pursuant to their power purchase contract with OVEC. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting regulatory liability, both of which are being amortized using the units-of-production method until March 2026. For information relating to the bankruptcy filing of a co-sponsor of OVEC and potential impact, see footnote (f) under “Guarantees and Other Assurances” in Note 13. See also Notes 7 , 13 and 18 for additional discussion of the power purchase agreement. 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. 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 the costs are incurred. No costs associated with planned major maintenance projects are accrued to PP&E in advance of the period in which the work is performed. 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. 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, except for certain instances in KU's FERC approved rates charged to its municipal customers, 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 $15 million in 2018 and $11 million in 2017 and 2016. 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. Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2018 2017 2016 PPL 2.77 % 2.65 % 2.73 % PPL Electric 3.01 % 2.86 % 2.63 % LKE 3.69 % 3.64 % 3.69 % LG&E 3.63 % 3.63 % 3.58 % KU 3.74 % 3.66 % 3.77 % (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 val

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2018
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: 2018 2017 2016 Operating Revenues from external customers (a) U.K. Regulated $ 2,268 $ 2,091 $ 2,207 Kentucky Regulated 3,214 3,156 3,141 Pennsylvania Regulated 2,277 2,195 2,156 Corporate and Other 26 5 13 Total $ 7,785 $ 7,447 $ 7,517 Depreciation U.K. Regulated $ 247 $ 230 $ 233 Kentucky Regulated 475 439 404 Pennsylvania Regulated 352 309 253 Corporate and Other 20 30 36 Total $ 1,094 $ 1,008 $ 926 Amortization (b) U.K. Regulated $ 34 $ 34 $ 16 Kentucky Regulated 18 24 29 Pennsylvania Regulated 22 33 32 Corporate and Other 4 6 3 Total $ 78 $ 97 $ 80 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ (190 ) $ 166 $ 13 Kentucky Regulated 6 6 6 Corporate and Other (2 ) 6 — Total $ (186 ) $ 178 $ 19 Interest Expense U.K. Regulated $ 413 $ 397 $ 402 Kentucky Regulated 274 261 260 Pennsylvania Regulated 159 142 129 Corporate and Other 117 101 97 Total $ 963 $ 901 $ 888 Income Before Income Taxes U.K. Regulated $ 1,339 $ 804 $ 1,479 Kentucky Regulated 531 645 640 Pennsylvania Regulated 567 575 550 Corporate and Other (152 ) (112 ) (119 ) Total $ 2,285 $ 1,912 $ 2,550 2018 2017 2016 Income Taxes (d) U.K. Regulated $ 225 $ 152 $ 233 Kentucky Regulated 120 359 242 Pennsylvania Regulated 136 216 212 Corporate and Other (23 ) 57 (39 ) Total $ 458 $ 784 $ 648 Deferred income taxes and investment tax credits (e) U.K. Regulated $ 118 $ 66 $ 31 Kentucky Regulated 94 294 291 Pennsylvania Regulated 125 257 221 Corporate and Other 18 90 17 Total $ 355 $ 707 $ 560 Net Income U.K. Regulated $ 1,114 $ 652 $ 1,246 Kentucky Regulated 411 286 398 Pennsylvania Regulated 431 359 338 Corporate and Other (129 ) (169 ) (80 ) Total $ 1,827 $ 1,128 $ 1,902 (a) See Note 1 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of 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: 2018 2017 2016 Expenditures for long-lived assets U.K. Regulated $ 954 $ 1,015 $ 1,031 Kentucky Regulated 1,117 892 791 Pennsylvania Regulated 1,196 1,254 1,134 Corporate and Other 1 10 1 Total $ 3,268 $ 3,171 $ 2,957 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2018 2017 Total Assets U.K. Regulated (a) $ 16,700 $ 16,813 Kentucky Regulated 15,078 14,468 Pennsylvania Regulated 11,257 10,082 Corporate and Other (b) 361 116 Total $ 43,396 $ 41,479 (a) Includes $12.4 billion and $12.5 billion of net PP&E as of December 31, 2018 and December 31, 2017 . 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: 2018 2017 2016 Revenues from external customers U.K. $ 2,268 $ 2,091 $ 2,207 U.S. 5,517 5,356 5,310 Total $ 7,785 $ 7,447 $ 7,517 As of December 31, 2018 2017 Long-Lived Assets U.K. $ 12,791 $ 12,851 U.S. 22,384 20,936 Total $ 35,175 $ 33,787 (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, 2018
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 typically 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 year ended December 31: 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) PPL includes $2.3 billion for the year ended December 31, 2018 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 for PPL Electric include the over/under-collection of its transmission formula rate. Alternative revenue programs for LKE, LG&E and KU include the over/under collection for the ECR and DSM programs as well as LG&E's over/under collection of its GLT program and KU's over/under collection of its generation formula rate. Over-collections of revenue are shown as positive amounts in the table above; under-collections are shown as negative amounts. (c) Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues. 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 $1.9 billion and $405 million for the year ended December 31, 2018 . The following table shows revenues from contracts with customers disaggregated by customer class for the year ended December 31: 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. 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: 2018 PPL $ 34 PPL Electric 24 LKE 9 LG&E 4 KU 5 The following table shows the balances of contract liabilities resulting from contracts with customers. PPL PPL Electric LKE LG&E KU Contract liabilities as of December 31, 2017 $ 29 $ 19 $ 8 $ 4 $ 4 Contract liabilities as of December 31, 2018 42 23 9 5 4 The following table shows the revenue recognized in 2018 that was included in the contract liability balance at the beginning of the year. 2018 PPL $ 21 PPL Electric 8 LKE 8 LG&E 4 KU 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, 2018 , PPL had $49 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $37 million within the next 12 months .

Preferred Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2018
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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 .
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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 .
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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 .
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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 . (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 2018 , 2017 or 2016 .

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2018
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 2018, these securities also included the PPL common stock forward sale agreements. See Note 8 for additional information on these agreements. The forward sale agreements are dilutive under the Treasury Stock Method to the extent the average stock price of PPL's common shares exceeds 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: 2018 2017 2016 Income (Numerator) Net income $ 1,827 $ 1,128 $ 1,902 Less amounts allocated to participating securities 2 2 6 Net income available to PPL common shareowners - Basic and Diluted $ 1,825 $ 1,126 $ 1,896 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 704,439 685,240 677,592 Add incremental non-participating securities: Share-based payment awards (a) 445 2,094 2,854 Forward sale agreements 3,735 — — Weighted-average shares - Diluted EPS 708,619 687,334 680,446 Basic EPS Net Income available to PPL common shareowners $ 2.59 $ 1.64 $ 2.80 Diluted EPS Net Income available to PPL common shareowners $ 2.58 $ 1.64 $ 2.79 (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): 2018 Stock-based compensation plans (a) 720 DRIP 1,974 (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 sale 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: 2018 2017 2016 Stock options 172 696 696 Performance units — — 176 Restricted stock units 11 — —

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income and Other Taxes	(All Registrants) 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 are effective for taxable years beginning after December 31, 2017. The TCJA included significant changes to the taxation of corporations, including provisions specifically applicable to regulated public utilities. The more significant changes that impact the Registrants were: • The reduction in the U.S. federal corporate income tax rate from a top marginal rate of 35% to a flat rate of 21%, effective January 1, 2018; • The exclusion from U.S. federal taxable income of dividends from foreign subsidiaries and the associated "transition tax;" • Limitations on the tax deductibility of interest expense, with an exception to these limitations for regulated public utilities; • Full current year expensing of capital expenditures with an exception for regulated public utilities that qualify for the exception to the interest expense limitation; and • The continuation of certain rate normalization requirements for accelerated depreciation benefits. For non-regulated businesses, the TCJA generally provides for full expensing of property acquired after September 27, 2017. Under GAAP, the tax effect of changes in tax laws must be recognized in the period in which the law is enacted, or December 2017 for the TCJA. The changes enacted by the TCJA were recorded as an adjustment to the Registrants' deferred tax provisions, and have been reflected in "Income Taxes" on the Statement of Income for the year ended December 31, 2017 as follows: PPL PPL Electric LKE LG&E KU Income tax expense (benefit) $ 321 $ (13 ) $ 112 $ — $ — The components of these adjustments are discussed below: Reduction of U.S. Federal Corporate Income Tax Rate GAAP requires deferred tax assets and liabilities to be measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. Thus, at the date of enactment, the Registrants' deferred taxes were remeasured based upon the U.S. federal corporate income tax rate of 21%. For PPL’s regulated entities, the changes in deferred taxes were, in large part, recorded as an offset to either a regulatory asset or regulatory liability and will be reflected in future rates charged to customers. The tax rate reduction impacts on non-regulated deferred tax assets and liabilities were recorded as an adjustment to the Registrants' deferred tax provisions, and have been reflected in "Income Taxes" on the Statement of Income for the year ended December 31, 2017 as follows: PPL PPL Electric LKE LG&E KU Income tax expense (benefit) $ 220 $ (13 ) $ 112 $ — $ — As indicated in Note 1 - "Summary of Significant Accounting Policies - Income Taxes", PPL’s U.S. regulated operations' accounting for income taxes are impacted by rate regulation. Therefore, reductions in accumulated deferred income tax balances due to the reduction in the U.S. federal corporate income tax rate to 21% under the provisions of the TCJA will result in amounts previously collected from utility customers for these deferred taxes to be refundable to such customers over a period of time. The TCJA includes provisions that stipulate how these excess deferred taxes are to be passed back to customers for certain accelerated tax depreciation benefits. Refunds of other deferred taxes either have been or will be determined by the Registrants’ regulators. The Balance Sheets at December 31, 2017 reflect 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 Transition Tax The TCJA 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 for purposes of the 2017 tax provision. As the PPL consolidated U.S. group had a taxable loss for 2017, inclusive of the taxable deemed dividend, the foreign tax credits associated with the deemed dividend were recorded as a deferred tax asset. However, it is expected that under the TCJA, the current and prior year foreign tax credit carryforwards will not be fully realizable. As a result, the net deferred income tax expense impact of the deemed repatriation was $101 million and was recorded in "Income Taxes" on the PPL Statement of Income for the year ended December 31, 2017 and "Deferred tax liabilities" on the PPL Balance Sheet at December 31, 2017. 2018 Impacts of TCJA The Registrants recognized certain provisional amounts relating to the impact of the enactment of the TCJA in their December 31, 2017 financial statements, in accordance with SEC guidance. Included in those provisional amounts were estimates of: tax depreciation, deductible executive compensation, accumulated foreign earnings, foreign tax credits, and deemed dividends from foreign subsidiaries, all of which were based on the interpretation and application of various provisions of the TCJA. In the third quarter of 2018, PPL filed its consolidated federal income tax return, which was prepared using guidance issued by the U.S. Treasury Department and the IRS since the filing of each Registrant's 2017 Form 10-K. Accordingly, the Registrants have updated the following provisional amounts and now consider them to be complete: (1) the amount of the deemed dividend and associated foreign tax credits relating to the transition tax imposed on accumulated foreign earnings as of December 31, 2017; (2) the amount of accelerated 100% "bonus" depreciation PPL was eligible to claim in its 2017 federal income tax return; and (3) the related impacts on PPL's 2017 consolidated federal net operating loss to be carried forward to future periods. In addition, the Registrants recorded the tax impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on the changes to deferred tax assets and liabilities resulting from the completed provisional amounts. The completed provisional amounts related to the tax rate reduction had an insignificant impact on the net regulatory liabilities of PPL's U.S. regulated operations. In the fourth quarter of 2018, PPL completed its analysis of the deductibility of executive compensation awarded as of November 2, 2017 and concluded that no material change to the provisional amounts is required. The final amounts reported in PPL's 2017 federal income tax return, provisional amounts for the year ended December 31, 2017, the related measurement period adjustments, and the resulting tax impact for the year ended December 31,2018 are as follows. Taxable Income (Loss) (a) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 397 $ 462 $ (65 ) Bonus Depreciation (b) (67 ) — (67 ) Consolidated Federal Net Operating Loss due to the TCJA (c) (330 ) (462 ) 132 Total $ — $ — $ — PPL Electric Bonus Depreciation (b) $ (39 ) $ — $ (39 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (68 ) (105 ) 37 Total $ (107 ) $ (105 ) $ (2 ) LKE Bonus Depreciation (b) $ (28 ) $ — $ (28 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (32 ) (45 ) 13 Total $ (60 ) $ (45 ) $ (15 ) LG&E Bonus Depreciation (b) $ (17 ) $ — $ (17 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 17 — 17 Total $ — $ — $ — KU Bonus Depreciation (b) $ (11 ) $ — $ (11 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 11 — 11 Total $ — $ — $ — (a) The above table reflects, for each item, the amount subject to change as a result of the TCJA and does not reflect the total amount of each item included in the return and the provision. (b) The TCJA increased the bonus depreciation percentage from 50% to 100% for qualified property acquired and placed in service after September 27, 2017 and before January 1, 2018. Increases in tax depreciation reduce the Registrants' taxes payable and increase net deferred tax liabilities with no impact to “Income Taxes” on the Statements of Income. (c) An increase in the consolidated federal net operating loss reduces net deferred tax liabilities with the opposite effect if there is a decrease in the consolidated federal net operating loss. These increases or decreases have no impact to “Income Taxes” on the Statements of Income. Income Tax Expense (Benefit) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 139 $ 161 $ (22 ) Foreign Tax Credits (157 ) (205 ) 48 Valuation of Foreign Tax Credit Carryforward 110 145 (35 ) Reduction in U.S. federal income tax rate 229 220 9 Total $ 321 $ 321 $ — PPL Electric Reduction in U.S. federal income tax rate $ (13 ) $ (13 ) $ — LKE Reduction in U.S. federal income tax rate $ 110 $ 112 $ (2 ) The Registrants' accounting related to the effects of the TCJA on financial results for the period ended December 31, 2017 is complete as of December 31, 2018 with respect to all provisional amounts. In 2018, the IRS issued proposed regulations for certain provisions of the TCJA, including interest deductibility, Base Erosion Anti-Avoidance Tax (BEAT), and Global Intangible Low-Taxed Income (GILTI). PPL has determined that the proposed regulations related to BEAT and GILTI do not materially change PPL's current interpretation of the statutory impact of these rules on the company. Proposed regulations relating to the limitation on the deductibility of interest expense were issued in November 2018 and such regulations provide detailed rules implementing the broader statutory provisions. These proposed regulations should not apply to the Registrants until the year in which the regulations are issued in final form, which is expected to be 2019. It is uncertain what form the final regulations will take and, therefore, the Registrants cannot predict what impact the final regulations will have on the tax deductibility of interest expense. However, if the proposed regulations were issued as final in their current form, the Registrants could have a limitation on a portion of their interest expense deduction for tax purposes and such limitation could be significant. (PPL) "Income Before Income Taxes" included the following: 2018 2017 2016 Domestic income $ 1,127 $ 874 $ 1,463 Foreign income 1,158 1,038 1,087 Total $ 2,285 $ 1,912 $ 2,550 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: 2018 2017 Deferred Tax Assets Deferred investment tax credits $ 31 $ 33 Regulatory liabilities 87 68 Income taxes due to customer 479 499 Accrued pension and postretirement costs 277 232 Federal loss carryforwards 325 356 State loss carryforwards 419 409 Federal and state tax credit carryforwards 392 455 Foreign capital loss carryforwards 313 329 Foreign loss carryforwards 1 2 Foreign - regulatory obligations — 2 Foreign - other 9 7 Contributions in aid of construction 139 134 Domestic - other 81 102 Unrealized losses on qualifying derivatives 7 10 Valuation allowances (808 ) (838 ) Total deferred tax assets 1,752 1,800 Deferred Tax Liabilities Domestic plant - net 3,359 3,168 Regulatory assets 314 288 Reacquired debt costs 12 15 Foreign plant - net 724 726 Foreign - pensions 83 32 Domestic - other 28 9 Total deferred tax liabilities 4,520 4,238 Net deferred tax liability $ 2,768 $ 2,438 State deferred taxes are determined on a by entity, by jurisdiction basis. As a result, $28 million and $24 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 2018 and 2017 . At December 31, 2018 , 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 $ 1,519 $ 319 $ — 2031-2037 Federal charitable contributions 29 6 — 2020-2022 State net operating losses 5,725 418 (370 ) 2019-2038 State charitable contributions 7 1 — 2020-2022 Foreign net operating losses 6 1 — Indefinite Foreign capital losses 1,842 313 (313 ) Indefinite Credit carryforwards Federal investment tax credit 133 — 2025-2036 Federal alternative minimum tax credit (a) 15 — Indefinite Federal foreign tax credits (b) 218 (113 ) 2024-2027 Federal - other 25 (8 ) 2019-2038 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 2018 $ 838 $ 26 $ — $ 56 (a) $ 808 2017 593 256 (b) — 11 838 2016 662 17 2 88 (c) 593 (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. (c) The reduction of the U.K. statutory income tax rate in 2016 resulted in a $19 million reduction in deferred tax assets and corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for additional information on the impact of the U.K. Finance Act 2016. In addition, deferred tax assets and corresponding valuation allowances were reduced in 2016 by approximately $65 million due to the effect of foreign currency exchange rates. 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, 2018 was $6.7 billion . The foregoing is not impacted by U.S. tax reform and the 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: 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ (19 ) $ 6 $ (14 ) Current - State 17 25 21 Current - Foreign 104 45 80 Total Current Expense 102 76 87 Deferred - Federal (a) 203 532 385 Deferred - State 100 88 89 Deferred - Foreign 107 133 86 Total Deferred Expense, excluding operating loss carryforwards 410 753 560 Amortization of investment tax credit (3 ) (3 ) (3 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal (20 ) (16 ) 25 Deferred - State (31 ) (26 ) (21 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards (51 ) (42 ) 4 Total income taxes $ 458 $ 784 $ 648 Total income tax expense - Federal $ 161 $ 519 $ 393 Total income tax expense - State 86 87 89 Total income tax expense - Foreign 211 178 166 Total income taxes $ 458 $ 784 $ 648 (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. 2018 2017 2016 Stock-based compensation recorded to Earnings reinvested $ — $ — $ (7 ) Other comprehensive income (6 ) (34 ) (6 ) Valuation allowance on state deferred taxes recorded to other comprehensive income — (1 ) 1 Total $ (6 ) $ (35 ) $ (12 ) 2018 2017 2016 Reconciliation of Income Tax Expense Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 480 $ 669 $ 893 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 40 46 46 Valuation allowance adjustments (b) 21 36 16 Impact of lower U.K. income tax rates(c) (25 ) (176 ) (177 ) U.S. income tax on foreign earnings - net of foreign tax credit (a)(d) 3 47 (42 ) Foreign income return adjustments — (8 ) 2 Impact of the U.K. Finance Act on deferred tax balances (e) (13 ) (16 ) (49 ) Depreciation and other items not normalized (11 ) (10 ) (10 ) Amortization of excess deferred federal and state income taxes(f) (37 ) — — Interest benefit on U.K. financing entities (17 ) (16 ) (17 ) Stock-based compensation 4 (3 ) (10 ) Deferred tax impact of U.S. tax reform (g) — 220 — Deferred tax impact of Kentucky tax reform (h) 9 — — Other (i) 4 (5 ) (4 ) Total increase (decrease) (22 ) 115 (245 ) Total income taxes $ 458 $ 784 $ 648 Effective income tax rate 20.0 % 41.0 % 25.4 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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. During 2018, 2017 and 2016, PPL recorded deferred income tax expense of $24 million , $16 million and $13 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 2018 compared with 2017. (d) During 2017, PPL recorded a federal income tax benefit of $35 million primarily attributable to U.K. pension contributions. During 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 . During 2016, PPL recorded lower income taxes primarily attributable to foreign tax credit carryforwards, arising from a decision to amend prior year tax returns to claim foreign tax credits rather than deduct foreign taxes. This decision was prompted by changes to the company's most recent business plan. (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 and recognized a $42 million deferred income tax benefit during 2016. (f) During 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. (g) During 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. (h) During 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. (i) During 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 above. 2018 2017 2016 Taxes, other than income State gross receipts $ 103 $ 102 $ 100 State capital stock — (6 ) — Foreign property 134 127 135 Domestic Other 75 69 66 Total $ 312 $ 292 $ 301 (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: 2018 2017 Deferred Tax Assets Accrued pension and postretirement costs $ 110 $ 81 Contributions in aid of construction 118 117 Regulatory liabilities 35 25 Income taxes due to customers 181 193 State loss carryforwards 14 19 Federal loss carryforwards 79 91 Other 25 27 Total deferred tax assets 562 553 Deferred Tax Liabilities Electric utility plant - net 1,681 1,544 Reacquired debt costs 6 8 Regulatory assets 176 150 Other 19 5 Total deferred tax liabilities 1,882 1,707 Net deferred tax liability $ 1,320 $ 1,154 PPL Electric expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. At December 31, 2018 , PPL Electric had the following loss carryforwards and related deferred tax assets: Gross Deferred Tax Asset Expiration Loss carryforwards Federal net operating losses $ 370 $ 78 2031-2037 Federal charitable contributions 6 1 2020-2022 State net operating losses 180 14 2031-2032 State charitable contributions 5 — 2020-2022 Credit carryforwards were insignificant at December 31, 2018 . 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. 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ 2 $ (65 ) $ (29 ) Current - State 9 20 19 Total Current Expense (Benefit) 11 (45 ) (10 ) Deferred - Federal (a) 96 234 193 Deferred - State 37 29 29 Total Deferred Expense, excluding operating loss carryforwards 133 263 222 Tax expense (benefit) of operating loss carryforwards Deferred - Federal (8 ) (5 ) — Total Tax Expense (Benefit) of Operating Loss Carryforwards (8 ) (5 ) — Total income taxes $ 136 $ 213 $ 212 Total income tax expense - Federal $ 90 $ 164 $ 164 Total income tax expense - State 46 49 48 Total income taxes $ 136 $ 213 $ 212 (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. 2018 2017 2016 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 119 $ 201 $ 193 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 43 36 36 Depreciation and other items not normalized (11 ) (8 ) (8 ) Amortization of excess deferred federal income taxes (a) (17 ) — — Stock-based compensation 1 (2 ) (6 ) Deferred tax impact of U.S. tax reform (b) — (13 ) — Other 1 (1 ) (3 ) Total increase (decrease) 17 12 19 Total income taxes $ 136 $ 213 $ 212 Effective income tax rate 24.0 % 37.0 % 38.4 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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. 2018 2017 2016 Taxes, other than income State gross receipts $ 103 $ 102 $ 100 Property and other 6 5 5 Total $ 109 $ 107 $ 105 (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: 2018 2017 Deferred Tax Assets Federal loss carryforwards $ 142 $ 150 State loss carryforwards 33 41 Federal tax credit carryforwards 169 181 Contributions in aid of construction 21 17 Regulatory liabilities 52 43 Accrued pension and postretirement costs 92 100 Income taxes due to customers 299 305 Deferred investment tax credits 32 33 Valuation allowances (8 ) (8 ) Other 29 33 Total deferred tax assets 861 895 Deferred Tax Liabilities Plant - net 1,671 1,615 Regulatory assets 138 138 Other 8 8 Total deferred tax liabilities 1,817 1,761 Net deferred tax liability $ 956 $ 866 At December 31, 2018 , 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 $ 674 $ 142 $ — 2031 - 2037 Federal charitable contributions 11 2 — 2020 - 2022 State net operating losses 848 33 — 2029 - 2038 Credit carryforwards Federal investment tax credit 133 — 2025 - 2028, 2036 Federal alternative minimum tax credit (a) 14 — Indefinite Federal - other 22 (8 ) 2019-2038 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 2018 $ 8 $ — $ — $ 8 2017 11 4 (a) 7 (b) 8 2016 12 — 1 (b) 11 (a) Federal tax credits expiring in 2021 that are more likely than not to expire before being utilized. (b) Federal tax credit 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: 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ 31 $ 74 $ (36 ) Current - State 4 6 1 Total Current Expense (Benefit) 35 80 (35 ) Deferred - Federal (a) 65 268 248 Deferred - State 34 32 38 Total Deferred Expense, excluding benefits of operating loss carryforwards 99 300 286 Amortization of investment tax credit - Federal (3 ) (3 ) (3 ) Tax benefit of operating loss carryforwards Deferred - Federal (2 ) (2 ) 10 Deferred - State — — (1 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards (2 ) (2 ) 9 Total income taxes (b) $ 129 $ 375 $ 257 Total income tax expense - Federal $ 91 $ 337 $ 219 Total income tax expense - State 38 38 38 Total income taxes (b) $ 129 $ 375 $ 257 (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) Excludes deferred federal and state tax expense (benefit) recorded to OCI of $5 million in 2018 , $(10) million in 2017 and $(16) million in 2016 . 2018 2017 2016 Reconciliation of Income Tax Expense Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 121 $ 242 $ 240 Increase (decrease) due to: State income taxes, net of federal income tax benefit 22 26 26 Amortization of investment tax credit (3 ) (3 ) (3 ) Amortization of excess deferred federal and state income taxes (b) (20 ) (2 ) (1 ) Stock-based compensation 1 1 (3 ) Deferred tax impact of U.S. tax reform (c) — 112 — Deferred tax impact of state tax reform (d) 9 — — Other (e) (1 ) (1 ) (2 ) Total increase 8 133 17 Total income taxes $ 129 $ 375 $ 257 Effective income tax rate 22.5 % 54.3 % 37.5 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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. (c) During 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) During 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) During 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 abov

Utility Rate Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2018
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. As a result of purchase accounting requirements, certain fair value amounts related to contracts that had favorable or unfavorable terms relative to market were recorded on the Balance Sheets with an offsetting regulatory asset or liability. LG&E and KU recover in customer rates the cost of power purchases. As a result, management believes the regulatory assets and liabilities created to offset the fair value amounts at LKE's acquisition date meet the recognition criteria established by existing accounting guidance and eliminate any rate-making impact of the fair value adjustments. LG&E's and KU's customer rates continue to reflect the original contracted prices for remaining contracts. (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 the levelized fuel factor and regulatory assets or liabilities recorded for 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 10 municipal customers for wholesale power requirements are calculated based on annual updates to a formula rate that utilizes a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except regulatory assets recorded for AROs related to certain CCR impoundments, 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 2018 2017 2018 2017 Current Regulatory Assets: Environmental cost recovery $ — $ 5 $ — $ — Generation formula rate — 6 — — Gas supply clause 12 4 — — Smart meter rider 11 15 11 15 Plant outage costs 10 3 — — Other 3 1 — 1 Total current regulatory assets (a) $ 36 $ 34 $ 11 $ 16 Noncurrent Regulatory Assets: Defined benefit plans $ 963 $ 880 $ 558 $ 504 Taxes recoverable through future rates 3 3 3 3 Storm costs 56 33 22 — Unamortized loss on debt 45 54 22 29 Interest rate swaps 20 26 — — Terminated interest rate swaps 87 92 — — Accumulated cost of removal of utility plant 200 173 200 173 AROs 273 234 — — Act 129 compliance rider 19 — 19 — Other 7 9 — — Total noncurrent regulatory assets $ 1,673 $ 1,504 $ 824 $ 709 Current Regulatory Liabilities: Generation supply charge $ 33 $ 34 $ 33 $ 34 Transmission service charge 3 9 3 9 Environmental cost recovery 16 1 — — Universal service rider 27 26 27 26 Transmission formula rate 3 9 3 9 TCJA customer refund 20 — 3 — Storm damage expense rider 5 8 5 8 Other 15 8 — — Total current regulatory liabilities $ 122 $ 95 $ 74 $ 86 PPL PPL Electric 2018 2017 2018 2017 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 674 $ 677 $ — $ — Power purchase agreement - OVEC 59 68 — — Net deferred taxes 1,826 1,853 629 668 Defined benefit plans 37 27 5 — Terminated interest rate swaps 72 74 — — TCJA customer refund 41 — 41 — Other 5 5 — — Total noncurrent regulatory liabilities $ 2,714 $ 2,704 $ 675 $ 668 LKE LG&E KU 2018 2017 2018 2017 2018 2017 Current Regulatory Assets: Plant outage costs $ 10 $ 3 $ 7 $ 3 $ 3 $ — Generation formula rate — 6 — — — 6 Gas supply clause 12 4 12 4 — — Other 3 5 2 5 1 — Total current regulatory assets $ 25 $ 18 $ 21 $ 12 $ 4 $ 6 Noncurrent Regulatory Assets: Defined benefit plans $ 405 $ 376 $ 249 $ 234 $ 156 $ 142 Storm costs 34 33 20 18 14 15 Unamortized loss on debt 23 25 15 16 8 9 Interest rate swaps 20 26 20 26 — — Terminated interest rate swaps 87 92 51 54 36 38 AROs 273 234 75 61 198 173 Other 7 9 1 2 6 7 Total noncurrent regulatory assets $ 849 $ 795 $ 431 $ 411 $ 418 $ 384 Current Regulatory Liabilities: Environmental cost recovery $ 16 $ 1 $ 6 $ — $ 10 $ 1 Fuel adjustment clauses — 3 — — — 3 Gas line tracker 2 3 2 3 — — TCJA customer refund 17 — 7 — 10 — Generation formula Rate 7 — — — 7 — Other 6 2 2 — 4 2 Total current regulatory liabilities $ 48 $ 9 $ 17 $ 3 $ 31 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 674 $ 677 $ 279 $ 282 $ 395 $ 395 Power purchase agreement - OVEC 59 68 41 47 18 21 Net deferred taxes 1,197 1,185 557 552 640 633 Defined benefit plans 32 27 — — 32 27 Terminated interest rate swaps 72 74 36 37 36 37 Other 5 5 2 1 3 4 Total noncurrent regulatory liabilities $ 2,039 $ 2,036 $ 915 $ 919 $ 1,124 $ 1,117 (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. Effective January 1, 2018, the Registrants adopted new accounting guidance that changes the income statement presentation of net periodic benefit cost and limits the capitalization to the service cost component of net periodic benefit cost. The non-service costs or credits that would have been capitalized under previous guidance are still able to be recovered through future base rates and are therefore now recognized as a regulatory asset or liability and amortized over the weighted average useful life of the asset base on which those non-service costs would have been capitalized. As of December 31, 2018, the regulatory liability balances were $11 million for PPL, $5 million for PPL Electric and $6 million for LKE and KU. As of December 31, 2018, the regulatory asset balances were $1 million for PPL, LKE and LG&E. (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, 2018 , the balances were $45 million for PPL and LKE, $25 million for LG&E and $20 million for KU. As of December 31, 2017 , the balances were $33 million for PPL and LKE, $18 million for LG&E and $15 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 . The amortization period of LG&E's and KU's regulatory assets for storm costs are subject to the results of the current Kentucky rate case discussed below in "Regulatory Matters - Kentucky Activities - Rate Case Proceedings." 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 LKE and 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 are currently distributing these amounts through the TCJA bill credit until tax-related savings will be reflected in base rates. PPL Electric's current liability relates to the period of July 1, 2018 through December 31, 2018 and will be credited back to distribution customers through a negative surcharge which became effective July 1, 2018. Additionally, PPL Electric's noncurrent liability balance relates to the period of January 1, 2018 through June 30, 2018 which is not yet reflected in distribution customer rates. PPL Electric must propose to the PUC the method by which it would like to return the amount of this liability to customers at the earlier of May 2021 or PPL Electric's next rate case. 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 will be amortized from 2019 through 2021. Taxes Recoverable through Future Rates Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred. 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). Under its SMP, PPL Electric will replace its current meters with new meters that meet the Act 129 requirements by the end of 2019. Under Act 129, EDCs are able to recover the costs and earn a return on capital of providing smart metering technology. PPL Electric uses a mechanism known as the Smart Meter Rider (SMR) to recover the costs to implement its SMP on a full and current basis. 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 9.7% 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 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 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. See Notes 1, 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 The Stipulation to the 2016 Kentucky rate case that became effective July 1, 2017 provided for the normalization of expenses associated with plant outages using an eight-year average. The eight-year average is comprised of four historical years' and four forecasted years' expenses. Plant outage expenses that are greater or less than the eight-year average will be collected from or returned to customers, through future base rates. Prior year plant outage liabilities are included within other current regulatory liabilities above. (PPL, LKE and LG&E) Gas Line Tracker The GLT authorizes LG&E to recover its incremental operating expenses, depreciation, property taxes and cost of capital, including a return on equity, for capital associated with the five year gas service riser, leak mitigation and customer service line ownership programs. As part of this program, LG&E makes necessary repairs to the gas distribution system and assumes ownership of service lines when replaced. In the 2016 rate case, the KPSC approved additional projects for recovery through the GLT mechanism related to further gas line replacements and transmission pipeline modernizations. Effective July 1, 2017, LG&E is authorized to earn a 9.7% return on equity for the GLT mechanism. As part of the 2016 rate case, LG&E now annually files a combined application which includes revised rates based on projected costs and a balancing adjustment calculation with rates effective on the first billing cycle in May. After the completion of a plan year, the balancing adjustment, as part of the combined application filing to the KPSC, amends rates charged for the differences between the actual costs and actual GLT charges for the preceding year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to these cost differences. 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 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 On September 28, 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. The proposed base rate increases would result in an electricity rate increase of 6.9% at KU and electricity and gas rate increases of 3% and 7.5% at LG&E. As discussed in the "TCJA Impact on LG&E and KU Rates" section below, LG&E's and KU's applications seek to include applicable changes associated with the TCJA in the calculation of the proposed base rates and to terminate the TCJA bill credit mechanism when the new base rates go into effect. New rates are expected to become effective on May 1, 2019. The applications are based on a forecasted test year of May 1, 2019 through April 30, 2020 with a requested return-on-equity of 10.42% . A number of parties have been granted intervention requests in the proceeding. Data discovery and the filing of written testimony will continue through February 2019 and a hearing is scheduled in March 2019. LG&E and KU cannot predict the outcome of these proceedings. CPCN Filing On January 10, 2018, LG&E and KU filed an application for a CPCN with the KPSC requesting approval for implementing Advanced Metering Systems across their Kentucky service territories, including gas operations for LG&E. The application projected completion in 2021 with estimated capital costs of $166 million and $155 million for LG&E and KU. On August 30, 2018, the KPSC issued an Order denying the CPCN for full deployment of the Advanced Metering Systems. The KPSC acknowledged the benefits of Advanced Metering Systems, expanded LG&E's and KU's Advanced Metering System pilot programs and encouraged LG&E and KU to consider other items to enhance the customer experience. This decision is not expected to have a significant impact on LG&E's and KU's results of operations. TCJA Impact on LG&E and KU Rates On December 21, 2017, Kentucky Industrial Utility Customers, Inc. submitted a complaint with the KPSC against LG&E and KU, as well as other utility companies in Kentucky, alleging that their respective rates would no longer be fair, just and reasonable following the enactment of the TCJA, which reduced the federal corporate tax rate from 35% to 21%. The complaint requested the KPSC to issue an order requiring LG&E and KU to begin deferring, as of January 1, 2018, the revenue requirement effect of all income tax expense savings resulting from the federal corporate income tax reduction, including the amortization of excess deferred income taxes by recording those savings in a regulatory liability account and establishing a process by which the federal corporate income tax savings will be passed back to customers. On January 29, 2018, LG&E, KU, Kentucky Industrial Utility Customers, Inc. and the Office of the Attorney General reached a settlement agreement to commence returning savings related to the TCJA to their customers through their ECR, DSM and LG&E's GLT rate mechanisms beginning in March 2018 and through a new bill credit mechanism from April 1, 2018 through April 30, 2019 and thereafter until tax-reform related savings are reflected in changes in base rates. The estimated impact of the rate reduction represents approximately $91 million in KU electricity revenues ( $70 million through the new bill credit and $21 million through existing rate mechanisms), $69 million in LG&E electricity revenues ( $49 million through the new bill credit and $20 million through existing rate mechanisms) and $17 million in LG&E gas revenues (substantially all through the new bill credit) for the period January 2018 through April 2019. On March 20, 2018, the KPSC issued an Order approving, with certain modifications, the settlement agreement reached between LG&E, KU, Kentucky Industrial Utility Customers, Inc. and the Office of the Attorney General. The KPSC estimates that, pursuant to its modifications, electricity revenues would incorporate reductions of approximately $108 million for KU ( $87 million through the new bill credit and $21 million through existing rate mechanisms) and $79 million for LG&E ( $59 million through the new bill credit and $20 million through existing rate mechanisms). This represents $27 million ( $17 million at KU and $10 million at LG&E) in additional reductions from the amounts proposed by the settlement. The KPSC's modifications to the settlement include certain changes in assumptions or inputs used in assessing tax reform or calculating LG&E's and KU's electricity rates. LG&E gas rate reductions were not modified significantly from the amount included in the settlement agreement. On September 28, 2018, the KPSC issued an Order on reconsideration, pursuant to LG&E's and KU's petition, implementing rates reflecting electricity revenue reductions of $101 million for KU ( $80 million through the new bill credit and $21 million through existing rate mechanisms), $74 million for LG&E electricity revenues ( $54 million through the new bill credit and $20 million through existing rate mechanisms) and $16 million LG&E gas revenues (substantially all through the new bill credit) for the period January 2018 through April 2019. This represents lower revenue reduction amounts than the March 20, 2018 Order of approximately $13 million ( $7 million at KU and $6 million at LG&E). In January 2018, the VSCC ordered KU, as well as other utilities in Virginia, to accrue regulatory liabilities reflecting the Virginia jurisdictional revenue requirement impacts of the reduced federal corporate tax rate. In March 2018, KU reached a settlement agreement regarding its rate case in Virginia. New rates, inclusive of TCJA impacts, were effective June 1, 2018. The settlement also stipulates that actual tax savings for the five month period prior to new rates taking effect would be addressed through KU's annual information filing for calendar year 2018. In May 2018, the VSCC approved the settlement agreement. The TCJA and rate case are not expected to have a significant impact on KU's financial condition or results of operations related to Virginia. On November 15, 2018, the FERC issued a Policy Statement which stated that the appropriate ratemaking treatment for changes in accumulated deferred income taxes as a result of the TCJA will be addressed in a Notice of Proposed Rulemaking. Also on November 15, 2018, the FERC issued the Notice of Proposed Rulemaking which proposes that public utility transmission providers include mechanisms in their formula rates to deduct excess accumulated deferred income taxes from, or add deficient accumulated deferred income taxes to, rate base and adjust their income tax allowances by amortized excess or deficient accumulated deferred income taxes. The Notice of Proposed Rulemaking did not prescribe the mechanism companies should use to adjust their formula rates. LG&E and KU are currently assessing the Notice of Proposed Rulemaking and are continuing to monitor guidance issued by the FERC. On February 5, 2019, in connection with a separate element of federal and Kentucky state tax reform effects, LG&E and KU filed a request with the FERC to amend their transmission formula rates, effective June 1, 2019, to incorporate reductions to corporate income tax rates as a result of the TCJA and HB 487. LG&E and KU do not anticipate the impact of the TCJA related to their FERC-jurisdictional rates to be significant. (LKE and LG&E) Gas Franchise LG&E’s gas franchise agreement for the Louisville/Jefferson County service area expired in March 2016. In August 2016, LG&E and Louisville/Jefferson County entered into a revised 5 -year franchise agreem

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2018
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 and "Long-term debt" on the December 31, 2017 Balance Sheet. The following credit facilities were in place at: December 31, 2018 December 31, 2017 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) (c) Jan. 2023 £ 210 £ 157 £ — £ 54 £ 148 £ — WPD (South West) Syndicated Credit Facility (a) (c) July 2021 245 — — 245 — — WPD (East Midlands) Syndicated Credit Facility (a) (c) July 2021 300 38 — 262 180 — WPD (West Midlands) Syndicated Credit Facility (a) (c) July 2021 300 — — 300 120 — Uncommitted Credit Facilities 130 — 4 126 — 4 Total U.K. Credit Facilities (b) £ 1,185 £ 195 £ 4 £ 987 £ 448 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Jan. 2023 $ 950 $ — $ 669 $ 281 $ — $ 230 Bilateral Credit Facility (c) (d) Mar. 2019 100 — 15 85 — 18 Total PPL Capital Funding Credit Facilities $ 1,050 $ — $ 684 $ 366 $ — $ 248 PPL Electric Syndicated Credit Facility (c) (d) Jan. 2023 $ 650 $ — $ 1 $ 649 $ — $ 1 LG&E Syndicated Credit Facility (c) (d) Jan. 2023 $ 500 $ — $ 279 $ 221 $ — $ 199 Term Loan Credit Facility (c) (e) Oct. 2019 200 200 — — 100 — Total LG&E Credit Facilities $ 700 $ 200 $ 279 $ 221 $ 100 $ 199 KU Syndicated Credit Facility (c) (d) Jan. 2023 $ 400 $ — $ 235 $ 165 $ — $ 45 Letter of Credit Facility (c) (d) (f) Oct. 2020 198 — 198 — — 198 Total KU Credit Facilities $ 598 $ — $ 433 $ 165 $ — $ 243 (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, 2018 and 2017 included USD-denominated borrowings of $200 million for both periods, which bore interest at 3.17% and 2.17% . The unused capacity reflects the amount borrowed in GBP of £156 million as of the date borrowed. The WPD (East Midlands) amount borrowed at December 31, 2018 and December 31, 2017 was a GBP-denominated borrowing, which equated to $48 million and $244 million and bore interest at 1.12% . and 0.89% . The WPD (West Midlands) amount borrowed at December 31, 2017 was a GBP-denominated borrowing, which equated to $162 million and bore interest at 0.89% . At December 31, 2018 , the unused capacity under the U.K. credit facilities was approximately $1.3 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, LKE, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, as it relates to the syndicated and bilateral credit facilities and subject to certain conditions, PPL Capital Funding may request that the capacity of its facility expiring in March 2019 be increased by up to $30 million , LG&E and KU each may request up to a $100 million increase in its facility's capacity. (e) LG&E entered into a term loan credit agreement in October 2017 whereby it may borrow up to $200 million . The outstanding borrowings at December 31, 2018 and December 31, 2017 bore interest at an average rate of 2.97% and 2.06% . (f) KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted to loans rather than requiring immediate payment. PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, as necessary. 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, 2018 December 31, 2017 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding 2.82% $ 1,000 $ 669 $ 331 1.64% $ 230 PPL Electric 650 — 650 — LG&E 2.94% 350 279 71 1.83% 199 KU 2.94% 350 235 115 1.97% 45 Total $ 2,350 $ 1,183 $ 1,167 $ 474 (PPL Electric, LKE, LG&E and KU) See Note 14 for discussion of intercompany borrowings. Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (g) 2018 2017 PPL U.S. Senior Unsecured Notes 3.88 % 2020 - 2047 $ 4,325 $ 4,575 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.99 % 2019 - 2048 7,705 7,314 Junior Subordinated Notes 5.68 % 2067 - 2073 930 930 Term Loan Credit Facility 2.97 % 2019 200 100 Total U.S. Long-term Debt 13,160 12,919 U.K. Senior Unsecured Notes (d) 5.13 % 2020 - 2040 6,471 6,351 Index-linked Senior Unsecured Notes (e) 1.45 % 2026 - 2056 1,063 1,012 Total U.K. Long-term Debt (f) 7,534 7,363 Total Long-term Debt Before Adjustments 20,694 20,282 Fair market value adjustments 16 21 Unamortized premium and (discount), net (e) 9 14 Unamortized debt issuance costs (120 ) (122 ) Total Long-term Debt 20,599 20,195 Less current portion of Long-term Debt 530 348 Total Long-term Debt, noncurrent $ 20,069 $ 19,847 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.22 % 2020 - 2048 $ 3,739 $ 3,339 Total Long-term Debt Before Adjustments 3,739 3,339 Unamortized discount (18 ) (16 ) Unamortized debt issuance costs (27 ) (25 ) Total Long-term Debt 3,694 3,298 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 3,694 $ 3,298 December 31, Weighted-Average Maturities (g) 2018 2017 LKE Senior Unsecured Notes 3.97 % 2020 - 2021 $ 725 $ 725 Term Loan Credit Facility 2.97 % 2019 200 100 First Mortgage Bonds (a) (c) 3.76 % 2019 - 2045 3,966 3,975 Long-term debt to affiliate 3.69 % 2026 - 2028 650 400 Total Long-term Debt Before Adjustments 5,541 5,200 Unamortized discount (13 ) (14 ) Unamortized debt issuance costs (26 ) (27 ) Total Long-term Debt 5,502 5,159 Less current portion of Long-term Debt 530 98 Total Long-term Debt, noncurrent $ 4,972 $ 5,061 LG&E Term Loan Credit Facility 2.97 % 2019 $ 200 $ 100 First Mortgage Bonds (a) (c) 3.58 % 2019 - 2045 1,624 1,624 Total Long-term Debt Before Adjustments 1,824 1,724 Unamortized discount (4 ) (4 ) Unamortized debt issuance costs (11 ) (11 ) Total Long-term Debt 1,809 1,709 Less current portion of Long-term Debt 434 98 Total Long-term Debt, noncurrent $ 1,375 $ 1,611 KU First Mortgage Bonds (a) (c) 3.89 % 2019 - 2045 $ 2,342 $ 2,351 Total Long-term Debt Before Adjustments 2,342 2,351 Unamortized discount (8 ) (9 ) Unamortized debt issuance costs (13 ) (14 ) Total Long-term Debt 2,321 2,328 Less current portion of Long-term Debt 96 — Total Long-term Debt, noncurrent $ 2,225 $ 2,328 (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 electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $9.4 billion and $8.5 billion at December 31, 2018 and 2017 . 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 $5.1 billion and $4.7 billion at December 31, 2018 and 2017 . 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 $6.3 billion and $6.0 billion at December 31, 2018 and 2017 . (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, 2018 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $505 million for LKE, comprised of $391 million and $114 million for LG&E and KU respectively. At December 31, 2018 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $375 million for LKE, comprised of $147 million and $228 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 ( $287 million at December 31, 2018 ) 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 2017 to 2018 was an increase of approximately £26 million ( $33 million ) resulting from inflation. In addition, this amount includes £319 million ( $407 million at December 31, 2018 ) 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 £5.3 billion ( $6.7 billion at December 31, 2018 ) 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, 2018 . 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 2019 through 2023 and thereafter are as follows: PPL PPL Electric LKE LG&E KU 2019 $ 530 $ — $ 530 $ 434 $ 96 2020 1,266 100 975 — 500 2021 1,248 400 348 98 — 2022 1,274 474 — — — 2023 2,233 90 13 — 13 Thereafter 14,143 2,675 3,675 1,292 1,733 Total $ 20,694 $ 3,739 $ 5,541 $ 1,824 $ 2,342 (PPL) In March 2018, WPD (South Wales) issued £30 million of 0.01% Index-linked Senior Notes due 2036 . WPD (South Wales) received proceeds of £31 million , which equated to $44 million at the time of issuance, net of fees and including a premium. The principal amount of the notes is adjusted based on changes in a specified index, as detailed in the terms of the related indenture. The proceeds were used for general corporate purposes. In May 2018, WPD (West Midlands) issued £30 million of 0.01% Index-linked Senior Notes due 2028 . WPD (West Midlands) received proceeds of £31 million , which equated to $41 million at the time of issuance, net of fees and including a premium. The principal amount of the notes is adjusted based on changes in a specified index, as detailed in the terms of the related indenture. The proceeds were used for general corporate purposes. In June 2018, PPL Capital Funding repaid the entire $250 million principal amount of its 1.90% Senior Note upon maturity. In October 2018, WPD plc issued £350 million of 3.5% Senior Notes due 2026 . WPD plc received proceeds of £346 million , which equated to $456 million at the time of issuance, net of fees and a discount. The proceeds were used for general corporate purposes. (PPL and PPL Electric) In June 2018, PPL Electric issued $ 400 million of 4.15% First Mortgage Bonds due 2048 . PPL Electric received proceeds of $ 394 million , net of a discount and underwriting fees, which were used to repay short-term debt and for general corporate purposes. (PPL, LKE and LG&E) In March 2018, the County of Trimble, Kentucky remarketed $28 million of Pollution Control Revenue Bonds, 2001 Series A (Louisville Gas and Electric Company Project) due 2026 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 2.30% through their mandatory purchase date of September 1, 2021 . In May 2018, the County of Trimble, Kentucky remarketed $35 million of Pollution Control Revenue Bonds, 2001 Series B (Louisville Gas and Electric Company Project) due 2027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 2.55% through their mandatory purchase date of May 3, 2021 . In May 2018, the County of Jefferson, Kentucky remarketed $35 million of Pollution Control Revenue Bonds, 2001 Series B (Louisville Gas and Electric Company Project) due 2027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 2.55% through their mandatory purchase date of May 3, 2021 . (LKE) In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028 . The proceeds were used to repay its outstanding notes payable to a PPL Energy Funding subsidiary. 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 63.25 million shares of PPL common stock. Full settlement of these forward sale agreements will occur no later than November 2019 . Upon any physical settlements of any forward sale agreement, PPL will issue and deliver to the applicable forward counterparty shares of its common stock in exchange for cash proceeds per share equal to the forward sale price. The forward sale price will be calculated based on an initial forward price of $26.7057 per share, reduced during the period the applicable forward contract is outstanding as specified in such forward sale agreement. PPL may, in certain circumstances, elect cash settlement or net share settlement for all or a portion of its rights or obligations under each forward sale agreement. The forward sale agreements are classified as equity transactions. PPL only receives proceeds and issues shares of common stock upon any settlements of the forward sale agreements. PPL intends to use net proceeds that it receives upon any settlement for general corporate purposes. 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 . For the unsettled portion of the agreements, the only impact to the financial statements will be the inclusion of incremental shares within the calculation of diluted EPS using the Treasury Stock Method. 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. PPL issued 4.2 million shares of common stock and received gross proceeds of $119 million for the year ended December 31, 2018. Distributions and Related Restrictions In November 2018 , PPL declared its quarterly common stock dividend, payable January 2, 2019 , at 41.0 cents per share (equivalent to $1.64 per annum). On February 14, 2019 , PPL announced that the company is increasing its common stock dividend to 41.25 cents per share on a quarterly basis (equivalent to $ 1.65 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, 2018 , 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 the acquisition of LKE by PPL. 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, 2018 , net assets of $2.8 billion ( $1.2 billion for LG&E and $1.6 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, 2018
Leases [Line Items]
Leases	(PPL, LKE, LG&E and KU) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land, gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11 Total future minimum rental payments for all operating leases are 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]
Leases	(PPL, LKE, LG&E and KU) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land, gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11 Total future minimum rental payments for all operating leases are 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]
Leases	(PPL, LKE, LG&E and KU) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land, gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11 Total future minimum rental payments for all operating leases are 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]
Leases	(PPL, LKE, LG&E and KU) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land, gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11 Total future minimum rental payments for all operating leases are 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, 2018
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, 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 are awards based on the fair value of PPL common stock on the date of grant. Actual PPL common shares will be issued upon completion of a restriction period, generally three years. Under the SIP, each restricted stock unit entitles the executive 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 service 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: 2018 2017 2016 PPL $ 30.58 $ 35.30 $ 33.84 PPL Electric 30.00 35.45 34.32 LKE 30.98 35.25 33.73 Restricted stock unit activity for 2018 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,291,649 $ 34.07 Granted 369,308 30.58 Vested (529,263 ) 32.97 Forfeited (33,491 ) 33.30 Nonvested, end of period (a) 1,098,203 33.45 PPL Electric Nonvested, beginning of period 184,416 $ 34.20 Transfer between registrants (2,906 ) 33.95 Granted 76,051 30.00 Vested (56,352 ) 32.39 Forfeited (13,872 ) 33.50 Nonvested, end of period 187,337 33.09 LKE Nonvested, beginning of period 231,557 $ 34.01 Transfer between registrants (1,284 ) 33.98 Granted 58,377 30.98 Vested (154,606 ) 33.38 Forfeited (1,014 ) 29.52 Nonvested, end of period 133,030 33.45 (a) Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards. 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: 2018 2017 2016 PPL $ 16 $ 20 $ 30 PPL Electric 2 3 3 LKE 5 4 5 Performance Units - Total Shareowner Return Performance units based on relative Total Shareowner Return (TSR) are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on TSR during a three -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 determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment except for 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: 2018 2017 2016 Expected stock volatility 17.60 % 17.40 % 19.60 % Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 TSR performance unit activity for 2018 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 978,231 $ 36.67 Granted 263,593 38.26 Vested (89,015 ) 34.78 Forfeited (a) (312,685 ) 35.26 Nonvested, end of period 840,124 37.89 PPL Electric Nonvested, beginning of period 75,513 $ 37.00 Granted 22,394 38.37 Vested (5,817 ) 35.34 Forfeited (a) (24,227 ) 36.27 Nonvested, end of period 67,863 37.86 TSR Performance Units Weighted- Average Grant Date Fair Value Per Share LKE Nonvested, beginning of period 180,289 $ 36.69 Granted 53,961 38.32 Vested (14,547 ) 35.04 Forfeited (a) (70,707 ) 35.91 Nonvested, end of period 148,996 37.81 (a) Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. The total fair value of TSR performance units vesting for the year ended December 31, 2018 , 2017 and 2016 was $3 million , $8 million and $12 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 determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment except for 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: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29 ROE performance unit activity for 2018 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 96,928 $ 34.42 Granted 234,664 32.21 Forfeited (2,634 ) 32.96 Nonvested, end of period 328,958 32.86 PPL Electric Nonvested, beginning of period 8,696 $ 34.41 Granted 19,899 32.32 Forfeited (2,635 ) 32.96 Nonvested, end of period 25,960 32.96 LKE Nonvested, beginning of period 20,539 $ 34.29 Granted 49,081 32.28 Nonvested, end of period 69,620 32.87 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, 2018 , 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 2018 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 3,762,183 $ 29.42 Exercised (151,750 ) 28.43 Forfeited (695,908 ) 42.87 Outstanding and exercisable at end of period 2,914,525 26.26 3.4 $ 6 For 2018 , 2017 and 2016 , PPL received $5 million , $19 million and $52 million in cash from stock options exercised. The related income tax benefits realized were not significant. The total intrinsic value of stock options exercised for 2018 was insignificant and was $8 million and $18 million for 2017 and 2016 . 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: 2018 2017 2016 PPL $ 25 $ 32 $ 27 PPL Electric 10 18 16 LKE 8 8 7 The income tax benefit related to above compensation expense was as follows: 2018 2017 2016 PPL $ 10 $ 13 $ 12 PPL Electric 3 8 7 LKE 2 3 3 At December 31, 2018 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 10 1.6 PPL Electric 2 1.7 LKE 1 1.4
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, 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 are awards based on the fair value of PPL common stock on the date of grant. Actual PPL common shares will be issued upon completion of a restriction period, generally three years. Under the SIP, each restricted stock unit entitles the executive 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 service 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: 2018 2017 2016 PPL $ 30.58 $ 35.30 $ 33.84 PPL Electric 30.00 35.45 34.32 LKE 30.98 35.25 33.73 Restricted stock unit activity for 2018 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,291,649 $ 34.07 Granted 369,308 30.58 Vested (529,263 ) 32.97 Forfeited (33,491 ) 33.30 Nonvested, end of period (a) 1,098,203 33.45 PPL Electric Nonvested, beginning of period 184,416 $ 34.20 Transfer between registrants (2,906 ) 33.95 Granted 76,051 30.00 Vested (56,352 ) 32.39 Forfeited (13,872 ) 33.50 Nonvested, end of period 187,337 33.09 LKE Nonvested, beginning of period 231,557 $ 34.01 Transfer between registrants (1,284 ) 33.98 Granted 58,377 30.98 Vested (154,606 ) 33.38 Forfeited (1,014 ) 29.52 Nonvested, end of period 133,030 33.45 (a) Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards. 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: 2018 2017 2016 PPL $ 16 $ 20 $ 30 PPL Electric 2 3 3 LKE 5 4 5 Performance Units - Total Shareowner Return Performance units based on relative Total Shareowner Return (TSR) are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on TSR during a three -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 determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment except for 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: 2018 2017 2016 Expected stock volatility 17.60 % 17.40 % 19.60 % Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 TSR performance unit activity for 2018 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 978,231 $ 36.67 Granted 263,593 38.26 Vested (89,015 ) 34.78 Forfeited (a) (312,685 ) 35.26 Nonvested, end of period 840,124 37.89 PPL Electric Nonvested, beginning of period 75,513 $ 37.00 Granted 22,394 38.37 Vested (5,817 ) 35.34 Forfeited (a) (24,227 ) 36.27 Nonvested, end of period 67,863 37.86 TSR Performance Units Weighted- Average Grant Date Fair Value Per Share LKE Nonvested, beginning of period 180,289 $ 36.69 Granted 53,961 38.32 Vested (14,547 ) 35.04 Forfeited (a) (70,707 ) 35.91 Nonvested, end of period 148,996 37.81 (a) Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. The total fair value of TSR performance units vesting for the year ended December 31, 2018 , 2017 and 2016 was $3 million , $8 million and $12 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 determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment except for 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: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29 ROE performance unit activity for 2018 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 96,928 $ 34.42 Granted 234,664 32.21 Forfeited (2,634 ) 32.96 Nonvested, end of period 328,958 32.86 PPL Electric Nonvested, beginning of period 8,696 $ 34.41 Granted 19,899 32.32 Forfeited (2,635 ) 32.96 Nonvested, end of period 25,960 32.96 LKE Nonvested, beginning of period 20,539 $ 34.29 Granted 49,081 32.28 Nonvested, end of period 69,620 32.87 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, 2018 , 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 2018 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 3,762,183 $ 29.42 Exercised (151,750 ) 28.43 Forfeited (695,908 ) 42.87 Outstanding and exercisable at end of period 2,914,525 26.26 3.4 $ 6 For 2018 , 2017 and 2016 , PPL received $5 million , $19 million and $52 million in cash from stock options exercised. The related income tax benefits realized were not significant. The total intrinsic value of stock options exercised for 2018 was insignificant and was $8 million and $18 million for 2017 and 2016 . 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: 2018 2017 2016 PPL $ 25 $ 32 $ 27 PPL Electric 10 18 16 LKE 8 8 7 The income tax benefit related to above compensation expense was as follows: 2018 2017 2016 PPL $ 10 $ 13 $ 12 PPL Electric 3 8 7 LKE 2 3 3 At December 31, 2018 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 10 1.6 PPL Electric 2 1.7 LKE 1 1.4
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, 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 are awards based on the fair value of PPL common stock on the date of grant. Actual PPL common shares will be issued upon completion of a restriction period, generally three years. Under the SIP, each restricted stock unit entitles the executive 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 service 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: 2018 2017 2016 PPL $ 30.58 $ 35.30 $ 33.84 PPL Electric 30.00 35.45 34.32 LKE 30.98 35.25 33.73 Restricted stock unit activity for 2018 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,291,649 $ 34.07 Granted 369,308 30.58 Vested (529,263 ) 32.97 Forfeited (33,491 ) 33.30 Nonvested, end of period (a) 1,098,203 33.45 PPL Electric Nonvested, beginning of period 184,416 $ 34.20 Transfer between registrants (2,906 ) 33.95 Granted 76,051 30.00 Vested (56,352 ) 32.39 Forfeited (13,872 ) 33.50 Nonvested, end of period 187,337 33.09 LKE Nonvested, beginning of period 231,557 $ 34.01 Transfer between registrants (1,284 ) 33.98 Granted 58,377 30.98 Vested (154,606 ) 33.38 Forfeited (1,014 ) 29.52 Nonvested, end of period 133,030 33.45 (a) Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards. 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: 2018 2017 2016 PPL $ 16 $ 20 $ 30 PPL Electric 2 3 3 LKE 5 4 5 Performance Units - Total Shareowner Return Performance units based on relative Total Shareowner Return (TSR) are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on TSR during a three -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 determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment except for 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: 2018 2017 2016 Expected stock volatility 17.60 % 17.40 % 19.60 % Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 TSR performance unit activity for 2018 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 978,231 $ 36.67 Granted 263,593 38.26 Vested (89,015 ) 34.78 Forfeited (a) (312,685 ) 35.26 Nonvested, end of period 840,124 37.89 PPL Electric Nonvested, beginning of period 75,513 $ 37.00 Granted 22,394 38.37 Vested (5,817 ) 35.34 Forfeited (a) (24,227 ) 36.27 Nonvested, end of period 67,863 37.86 TSR Performance Units Weighted- Average Grant Date Fair Value Per Share LKE Nonvested, beginning of period 180,289 $ 36.69 Granted 53,961 38.32 Vested (14,547 ) 35.04 Forfeited (a) (70,707 ) 35.91 Nonvested, end of period 148,996 37.81 (a) Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. The total fair value of TSR performance units vesting for the year ended December 31, 2018 , 2017 and 2016 was $3 million , $8 million and $12 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 determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment except for 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: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29 ROE performance unit activity for 2018 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 96,928 $ 34.42 Granted 234,664 32.21 Forfeited (2,634 ) 32.96 Nonvested, end of period 328,958 32.86 PPL Electric Nonvested, beginning of period 8,696 $ 34.41 Granted 19,899 32.32 Forfeited (2,635 ) 32.96 Nonvested, end of period 25,960 32.96 LKE Nonvested, beginning of period 20,539 $ 34.29 Granted 49,081 32.28 Nonvested, end of period 69,620 32.87 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, 2018 , 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 2018 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 3,762,183 $ 29.42 Exercised (151,750 ) 28.43 Forfeited (695,908 ) 42.87 Outstanding and exercisable at end of period 2,914,525 26.26 3.4 $ 6 For 2018 , 2017 and 2016 , PPL received $5 million , $19 million and $52 million in cash from stock options exercised. The related income tax benefits realized were not significant. The total intrinsic value of stock options exercised for 2018 was insignificant and was $8 million and $18 million for 2017 and 2016 . 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: 2018 2017 2016 PPL $ 25 $ 32 $ 27 PPL Electric 10 18 16 LKE 8 8 7 The income tax benefit related to above compensation expense was as follows: 2018 2017 2016 PPL $ 10 $ 13 $ 12 PPL Electric 3 8 7 LKE 2 3 3 At December 31, 2018 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 10 1.6 PPL Electric 2 1.7 LKE 1 1.4

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2018
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. 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 Retirement 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 2018 2017 2016 2018 2017 2016 2018 2017 2016 Net periodic defined benefit costs (credits): Service cost $ 62 $ 65 $ 66 $ 82 $ 76 $ 69 $ 7 $ 7 $ 7 Interest cost 156 168 174 185 178 235 21 23 26 Expected return on plan assets (249 ) (231 ) (228 ) (587 ) (514 ) (504 ) (23 ) (22 ) (22 ) Amortization of: Prior service cost (credit) 10 10 8 — — — (1 ) (1 ) — Actuarial (gain) loss 84 69 50 151 144 138 — 1 1 Net periodic defined benefit costs (credits) prior to settlements and termination benefits 63 81 70 (169 ) (116 ) (62 ) 4 8 12 Settlements — 1 3 — — — — — — Termination benefits — 1 — — — — — — — Net periodic defined benefit costs (credits) $ 63 $ 83 $ 73 $ (169 ) $ (116 ) $ (62 ) $ 4 $ 8 $ 12 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement — (1 ) (3 ) — — — — — — Net (gain) loss 157 27 253 201 346 7 8 (28 ) 9 Prior service cost (credit) 1 (1 ) 15 13 — — — 8 — Amortization of: Prior service (cost) credit (10 ) (10 ) (8 ) — — — 1 1 (1 ) Actuarial gain (loss) (84 ) (69 ) (50 ) (151 ) (144 ) (138 ) — (1 ) (1 ) Total recognized in OCI and regulatory assets/liabilities (a) 64 (54 ) 207 63 202 (131 ) 9 (20 ) 7 Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (a) $ 127 $ 29 $ 280 $ (106 ) $ 86 $ (193 ) $ 13 $ (12 ) $ 19 (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 2018 2017 2016 2018 2017 2016 OCI $ 90 $ (53 ) $ 236 $ 20 $ (25 ) $ 7 Regulatory assets/liabilities (26 ) (1 ) (29 ) (11 ) 5 — Total recognized in OCI and regulatory assets/liabilities $ 64 $ (54 ) $ 207 $ 9 $ (20 ) $ 7 (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 2018 2017 2016 2018 2017 2016 Net periodic defined benefit costs (credits): Service cost $ 25 $ 24 $ 23 $ 4 $ 4 $ 5 Interest cost 63 68 71 8 9 9 Expected return on plan assets (102 ) (92 ) (91 ) (9 ) (7 ) (6 ) Amortization of: Prior service cost 9 8 8 1 1 3 Actuarial (gain) loss (a) 35 31 21 — — (1 ) Net periodic defined benefit costs (b) $ 30 $ 39 $ 32 $ 4 $ 7 $ 10 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (gain) loss $ 40 $ 30 $ 119 $ 1 $ (14 ) $ 6 Prior service cost — 7 — — 8 — Amortization of: Prior service credit (9 ) (8 ) (8 ) (1 ) (1 ) (3 ) Actuarial gain (loss) (35 ) (32 ) (21 ) — — 1 Total recognized in OCI and regulatory assets/liabilities (4 ) (3 ) 90 — (7 ) 4 Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 26 $ 36 $ 122 $ 4 $ — $ 14 (a) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LKE's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $11 million in 2018 and 2017 and $6 million in 2016 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $6 million in 2018 and $5 million in 2017 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice. 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 2018 2017 2016 2018 2017 2016 OCI $ (25 ) $ 33 $ 42 $ 4 $ (2 ) $ 2 Regulatory assets/liabilities 21 (36 ) 48 (4 ) (5 ) 2 Total recognized in OCI and regulatory assets/liabilities $ (4 ) $ (3 ) $ 90 $ — $ (7 ) $ 4 (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 2018 2017 2016 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 $ 1 Interest cost 12 13 15 Expected return on plan assets (22 ) (22 ) (21 ) Amortization of: Prior service cost 5 5 4 Actuarial loss (a) 7 9 7 Net periodic defined benefit costs (b) $ 3 $ 6 $ 6 Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: Net (gain) loss $ 22 $ (9 ) $ 22 Prior service cost — 7 — Amortization of: Prior service credit (5 ) (5 ) (4 ) Actuarial gain (7 ) (9 ) (7 ) Total recognized in regulatory assets/liabilities 10 (16 ) 11 Total recognized in net periodic defined benefit costs and regulatory assets $ 13 $ (10 ) $ 17 (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 $2 million in 2018 , $7 million in 2017 and $5 million in 2016 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $6 million in 2018 and $5 million in 2017 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice. (All Registrants) The following net periodic defined benefit costs (credits) were charged to expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2018 2017 2016 2018 2017 2016 2018 2017 2016 PPL $ 40 $ 59 $ 53 $ (226 ) $ (151 ) $ (95 ) $ 2 $ 5 $ 7 PPL Electric (a) 4 12 10 (1 ) — 1 LKE (b) 21 28 24 3 5 6 LG&E (b) 4 8 8 2 3 3 KU (a) (b) 2 4 5 1 1 2 (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, $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2018 , $4 million for LG&E and $2 million for KU were recorded as regulatory assets in 2017 and $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2016 . 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 2018 2017 2016 2018 2017 2016 LG&E Non-Union Only $ 2 $ 5 $ 4 $ 2 $ 3 $ 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. For 2016, PPL, LKE and LG&E estimated projected mortality improvements using the IRS BB-2D two-dimensional improvement scale on a generational basis 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 continue to use this improvement scale in 2018. 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 2018 2017 2018 2017 2018 2017 PPL Discount rate 4.35 % 3.70 % 2.98 % 2.65 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.78 % 3.50 % 3.50 % 3.76 % 3.75 % LKE Discount rate 4.35 % 3.69 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 4.33 % 3.65 % 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 2018 2017 2016 2018 2017 2016 2018 2017 2016 PPL Discount rate service cost 3.70 % 4.21 % 4.59 % 2.73 % 2.99 % 3.90 % 3.64 % 4.11 % 4.48 % Discount rate interest cost 3.70 % 4.21 % 4.59 % 2.31 % 2.41 % 3.14 % 3.64 % 4.11 % 4.48 % Rate of compensation increase 3.78 % 3.95 % 3.93 % 3.50 % 3.50 % 4.00 % 3.75 % 3.92 % 3.91 % Expected return on plan assets 7.25 % 7.00 % 7.00 % 7.23 % 7.22 % 7.20 % 6.40 % 6.21 % 6.11 % LKE Discount rate 3.69 % 4.19 % 4.56 % 3.65 % 4.12 % 4.49 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.00 % 7.00 % 7.15 % 6.82 % 6.82 % LG&E Discount rate 3.65 % 4.13 % 4.49 % Expected return on plan assets (a) 7.25 % 7.00 % 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: 2018 2017 2016 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.6 % 6.6 % 7.0 % – cost 6.6 % 7.0 % 6.8 % 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 2023 2022 2022 – cost 2022 2022 2020 (PPL) The funded status of PPL's plans at December 31 was as follows: Pension Benefits U.S. U.K. Other Postretirement Benefits 2018 2017 2018 2017 2018 2017 Change in Benefit Obligation Benefit Obligation, beginning of period $ 4,288 $ 4,079 $ 8,219 $ 7,383 $ 589 $ 591 Service cost 62 65 82 76 7 7 Interest cost 156 168 185 178 21 23 Participant contributions — — 13 13 13 14 Plan amendments 1 (1 ) 12 — — 8 Actuarial (gain) loss (352 ) 233 (406 ) 293 (34 ) 4 Settlements — (6 ) — (1 ) — — Termination benefits — 1 — — — — Gross benefits paid (272 ) (251 ) (381 ) (345 ) (58 ) (59 ) Federal subsidy — — — — — 1 Currency conversion — — (449 ) 622 — — Benefit Obligation, end of period 3,883 4,288 7,275 8,219 538 589 Change in Plan Assets Plan assets at fair value, beginning of period 3,488 3,243 8,490 7,211 405 378 Actual return on plan assets (260 ) 437 (30 ) 480 (20 ) 54 Employer contributions 153 65 188 486 23 15 Participant contributions — — 13 13 11 13 Transfer out (a) — — — — (65 ) — Settlements — (6 ) — (1 ) — — Gross benefits paid (272 ) (251 ) (381 ) (345 ) (53 ) (55 ) Currency conversion — — (479 ) 646 — — Plan assets at fair value, end of period 3,109 3,488 7,801 8,490 301 405 Funded Status, end of period $ (774 ) $ (800 ) $ 526 $ 271 $ (237 ) $ (184 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ — $ — $ 535 $ 284 $ 2 $ 2 Current liability (13 ) (13 ) (1 ) — (3 ) (3 ) Noncurrent liability (761 ) (787 ) (8 ) (13 ) (236 ) (183 ) Net amount recognized, end of period $ (774 ) $ (800 ) $ 526 $ 271 $ (237 ) $ (184 ) Pension Benefits U.S. U.K. Other Postretirement Benefits 2018 2017 2018 2017 2018 2017 Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 40 $ 49 $ 12 $ — $ 10 $ 9 Net actuarial (gain) loss 1,207 1,134 2,806 2,755 24 16 Total (b) $ 1,247 $ 1,183 $ 2,818 $ 2,755 $ 34 $ 25 Total accumulated benefit obligation for defined benefit pension plans $ 3,668 $ 4,000 $ 6,689 $ 7,542 (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 2018 2017 2018 2017 AOCI $ 370 $ 374 $ 21 $ 15 Regulatory assets/liabilities 877 809 13 10 Total $ 1,247 $ 1,183 $ 34 $ 25 The actuarial (gain) loss for all pension plans in 2018 and 2017 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 2018 2017 2018 2017 Projected benefit obligation $ 3,883 $ 4,288 $ 9 $ 3,083 Fair value of plan assets 3,109 3,488 — 3,070 U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2018 2017 2018 2017 Accumulated benefit obligation $ 3,668 $ 4,000 $ 9 $ 10 Fair value of plan assets 3,109 3,488 — — (LKE) The funded status of LKE's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,771 $ 1,669 $ 223 $ 220 Service cost 25 24 4 4 Interest cost 63 68 8 9 Participant contributions — — 8 8 Plan amendments (a) — 6 — 8 Actuarial (gain) loss (b) (168 ) 113 (16 ) (7 ) Gross benefits paid (a) (111 ) (109 ) (22 ) (19 ) Benefit Obligation, end of period 1,580 1,771 205 223 Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 Change in Plan Assets Plan assets at fair value, beginning of period 1,402 1,315 116 98 Actual return on plan assets (106 ) 175 (9 ) 14 Employer contributions 109 21 24 15 Participant contributions — — 8 8 Gross benefits paid (111 ) (109 ) (22 ) (19 ) Plan assets at fair value, end of period 1,294 1,402 117 116 Funded Status, end of period $ (286 ) $ (369 ) $ (88 ) $ (107 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ — $ — $ 2 $ 2 Current liability (4 ) (4 ) (3 ) (3 ) Noncurrent liability (282 ) (365 ) (87 ) (106 ) Net amount recognized, end of period $ (286 ) $ (369 ) $ (88 ) $ (107 ) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost $ 35 $ 44 $ 12 $ 13 Net actuarial (gain) loss 439 434 (25 ) (26 ) Total $ 474 $ 478 $ (13 ) $ (13 ) Total accumulated benefit obligation for defined benefit pension plans $ 1,467 $ 1,616 (a) The pension plans were amended in December 2015 to allow active participants and terminated vested participants who had not previously elected a form of payment of their benefit to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. Gross benefits paid by the plans include lump-sum cash payments made to participants during 2018 and 2017 of $52 million and $50 million in connection with these offerings. (b) The actuarial (gain) loss for all pension plans in 2018 and 2017 was primarily related to change 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 2018 2017 2018 2017 AOCI $ 118 $ 144 $ 10 $ 6 Regulatory assets/liabilities 356 334 (23 ) (19 ) Total $ 474 $ 478 $ (13 ) $ (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 2018 2017 Projected benefit obligation $ 1,580 $ 1,771 Fair value of plan assets 1,294 1,402 ABO in excess of plan assets 2018 2017 Accumulated benefit obligation $ 1,467 $ 1,616 Fair value of plan assets 1,294 1,402 (LG&E) The funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2018 2017 Change in Benefit Obligation Benefit Obligation, beginning of period $ 326 $ 329 Service cost 1 1 Interest cost 12 13 Plan amendments (a) — 6 Actuarial (gain) loss (24 ) 11 Gross benefits paid (a) (30 ) (34 ) Benefit Obligation, end of period 285 326 Change in Plan Assets Plan assets at fair value, beginning of period 325 318 Actual return on plan assets (24 ) 41 Employer contributions 10 — Gross benefits paid (30 ) (34 ) Plan assets at fair value, end of period 281 325 Funded Status, end of period $ (4 ) $ (1 ) Amounts recognized in the Balance Sheets consist of: Noncurrent liability $ (4 ) $ (1 ) Net amount recognized, end of period $ (4 ) $ (1 ) Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost $ 22 $ 27 Net actuarial loss 107 92 Total $ 129 $ 119 Total accumulated benefit obligation for defined benefit pension plan $ 285 $ 326 (a) The pension plan was amended in December 2015 to allow active participants and terminated vested participants who had not previously elected a form of payment of their benefit to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. Gross benefits paid by the plan include lump-sum cash payments made to participants during 2018 and 2017 of $16 million and $19 million in connection with this offering. LG&E's pension plan had projected and accumulated benefit obligations in excess of plan assets at December 31, 2018 and 2017 . 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 liabilities at December 31 as follows: 2018 2017 Pension $ 7 $ 44 Other postretirement benefits 65 74 (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: 2018 2017 Pension $ 285 $ 246 Other postretirement benefits 120 62 (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 liabilities at December 31 as follows. 2018 2017 Pension $ 1 $ 36 Other postretirement benefits 25 32 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 2018 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 2018 2018 (a) 2017 (a) Target Asset Allocation (a) Growth Portfolio 55 % 56 % 55 % Equity securities 30 % 32 % Debt securities (b) 15 % 14 % Alternative investments 10 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (b) 39 % 39 % Derivatives 4 % 4 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes. (LKE) LKE has pension plans, 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 $1.3 billion and $1.4 billion at December 31, 2018 and 2017 represents an interest of approximately 42% and 40% 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 $281 million and $325 million at December 31, 2018 and 2017 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, 2018 December 31, 2017 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 $ 220 $ 220 $ — $ — $ 301 $ 301 $ — $ — Equity securities: U.S. Equity 159 159 — — 229 229 — — U.S. Equity fund measured at NAV (a) 340 — — — 364 — — — International equity fund at NAV (a) 466 — — — 538 — — — Commingled debt measured at NAV (a) 543 — — — 611 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 212 212 — — 186 186 — — Corporate 899 — 874 25 883 — 870 13 Other 17 — 17 — 10 — 10 — Alternative investments: Real estate measured at NAV (a) 90 — — — 109 — — — Private equity measured at NAV (a) 65 — — — 80 — — — Hedge funds measured at NAV (a) 175 — — — 175 — — — December 31, 2018 December 31, 2017 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 33 — 33 — 51 — 51 — Insurance contracts 21 — — 21 24 — — 24 PPL Services Corporation Master Trust assets, at fair value 3,240 $ 591 $ 924 $ 46 3,561 $ 716 $ 931 $ 37 Receivables and payables, net (b) (2 ) 72 401(h) accounts restricted for other postretirement benefit obligations (129 ) (145 ) Total PPL Services Corporation Master Trust pension assets $ 3,109 $ 3,488 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2017 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 27 $ 40 Actual return on plan assets Relating to assets still held at the reporting date — 1 1 Purchases, sales and settlements — (4 ) (4 ) Balance at end of period $ 13 $ 24 $ 37 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 mor

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2018
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LKE, LG&E and KU) At December 31, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 — 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, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 — 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, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 — 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, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 — 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, 2018
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 2020 Natural Gas Retail Supply 2020 Coal 2023 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 2019 $ 19 $ 8 $ 27 2020 18 8 26 2021 19 8 27 2022 19 8 27 2023 19 8 27 Thereafter 297 133 430 Total $ 391 $ 173 $ 564 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2018 2017 2016 LG&E $ 14 $ 14 $ 16 KU 6 6 7 Total $ 20 $ 20 $ 23 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, PPL Montana entered into an agreement to sell its hydroelectric generating facilities. In June 2014, PPL and PPL Energy Supply 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 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 are proceeding with limited jurisdictional discovery. 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. 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. The parties are proceeding with limited jurisdictional discovery in connection with the motion to remand. 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. In addition, the complaint asks the court to order, on behalf of creditors, the recovery of a $500 million "special cash dividend" that Riverstone extracted from Talen Energy in December 2017. On January 11, 2019, the PPL plaintiffs filed an amended complaint, adding claims related to indemnification with respect to the Talen Direct Action and the Talen Putative Class Action (together, the Montana Actions) and requested a declaration that the Montana Actions are time-barred under the spinoff agreements. On February 11, 2019, the defendants filed motions to dismiss the amended complaint. 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 Montana Actions and intends to vigorously defend against these actions. The Montana Actions and the Delaware Action are all in the 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. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the Cane Run plant, which retired three coal-fired units in 2015. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In July 2014, the court dismissed the RCRA claims and all but one Clean Air Act claim, but declined to dismiss the common law tort claims. In November 2016, the plaintiffs filed an amended complaint removing the personal injury claims and removing certain previously named plaintiffs. In February 2017, the U.S. District Court issued an Order dismissing PPL as a defendant and dismissing the final federal claim against LG&E. In April 2017, the U.S. District Court issued an Order declining to exercise supplemental jurisdiction on the state law claims and dismissed 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. Proceedings are currently underway regarding potential class certification, for which a decision may be rendered in 2019. 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 On July 12, 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. On December 28, 2017 the U.S. District Court issued an Order dismissing the Clean Water Act and RCRA complaints against KU in their entirety. On January 26, 2018, the plaintiffs appealed the dismissal Order to the U.S. Court of Appeals for the Sixth Circuit. On September 24, 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 and reversing its dismissal of the RCRA claims against KU and remanding the latter to the U.S. District Court. On October 9, 2018, KU filed a petition for rehearing to the U.S. Court of Appeals for the Sixth Circuit regarding the RCRA claims. On November 27, 2018, the U.S. Court of Appeals for the Sixth Circuit denied KU's petition for rehearing regarding the RCRA claims. On January 8, 2019, KU filed an answer to plaintiffs’ complaint in the U.S. District Court. 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. A final report of KU's findings is expected to be submitted to the KEEC in 2019. KU believes that current and planned measures for the E.W. Brown plant, including closure of impoundments, cessation of certain discharges and deployment of new discharge controls, are sufficient to ensure compliance with applicable requirements. However, until completion of the aquatic study and related assessments and issuance of regulatory determinations by the KEEC, PPL, LKE and KU are unable to determine whether additional remedial measures will be required at the E.W. Brown plant. (All Registrants) 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. Environmental Matters (All Registrants) Due to the environmental issues discussed below or other environmental matters, it may be necessary for the Registrants to modify, curtail, replace or cease operation of certain facilities or performance of certain operations to comply with statutes, regulations and other requirements of regulatory bodies or courts. In addition, legal challenges to new environmental permits or rules add to the uncertainty of estimating the future cost of these permits and rules. Finally, the regulatory reviews specified in the President's March 2017 Executive Order (the March 2017 Executive Order) promoting energy independence and economic growth could result in future regulatory changes and additional uncertainty. WPD's distribution businesses are subject to certain statutory and regulatory environmental requirements. It may be necessary for WPD to incur significant compliance costs, which costs may be recoverable through rates subject to the approval of Ofgem. PPL believes that WPD has taken and continues to take measures to comply with all applicable environmental laws and regulations. LG&E and KU are entitled to recover, through the ECR mechanism, certain costs of complying with the Clean Air Act, as amended, and those federal, state or local environmental requirements applicable to coal combustion wastes and by-products from facilities that generate electricity from coal in accordance with approved compliance plans. Costs not covered by the ECR mechanism for LG&E and KU and all such costs for PPL Electric are subject to rate recovery before the companies' respective state regulatory authorities, or the FERC, if applicable. Because neither WPD nor PPL Electric owns any generating plants, their exposure to related environmental compliance costs is reduced. PPL, PPL Electric, LKE, LG&E and KU can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities. Air (PPL, LKE, LG&E and KU) NAAQS The Clean Air Act, which regulates air pollutants from mobile and stationary sources in the United States, has a significant impact on the operation of fossil fuel generation plants. Among other things, the Clean Air Act requires the EPA periodically to review and establish concentration levels in the ambient air for six pollutants to protect public health and welfare. The six pollutants are carbon monoxide, lead, nitrogen dioxide, ozone (contributed to by nitrogen oxide emissions), particulate matter and sulfur dioxide. The established concentration levels for these six pollutants are known as NAAQS. Under the Clean Air Act, the EPA is required to reassess the NAAQS on a five-year schedule. Federal environmental regulations of these six pollutants require states to adopt implementation plans, known as state implementation plans, which detail how the state will attain the standards that are mandated by the relevant law or regulation. Each state identifies the areas within its boundaries that meet the NAAQS (attainment areas) and those that do not (non-attainment areas), and must develop a state implementation plan both to bring non-attainment areas into compliance with the NAAQS and to maintain good air quality in attainment areas. In addition, for attainment of ozone and fine particulates standards, states in the eastern portion of the country, including Kentucky, are subject to a regional program developed by the EPA known as the Cross-State Air Pollution Rule. The NAAQS, future revisions to the NAAQS and state implementation plans, or future revisions to regional programs, may require installation of additional pollution controls, the costs of which PPL, LKE, LG&E and KU believe are subject to cost recovery. Although PPL, LKE, LG&E and KU do not anticipate significant costs to comply with these programs, changes in market or operating conditions could result in different costs than anticipated. Ozone The EPA issued the current ozone standard in October 2015. The states and the EPA are required to determine (based on ambient air monitoring data) those areas that meet the standard and those that are in nonattainment. The EPA was scheduled to designate areas as being in attainment or nonattainment of the current ozone standard by no later than October 2017 which was to be followed by further regulatory proceedings identifying compliance measures and deadlines. However, the current implementation and compliance schedule is uncertain because the EPA failed to make nonattainment designations by the applicable deadline. In addition, some industry groups have requested the EPA to defer implementation of the 2015 ozone standard, but the EPA has not yet acted on this request. Although implementation of the 2015 ozone standard could potentially require the addition of SCRs at some LG&E and KU generating units, PPL, LKE, LG&E and KU are currently unable to determine what the compliance measures and deadlines may ultimately be with respect to the new standard. States are also obligated to address interstate transport issues associated with ozone standards through the establishment of "good neighbor" state implementation plans for those states that are found to contribute significantly to another state's non-attainment. As a result of a partial consent decree addressing claims regarding federal implementation, the EPA and several states, including Kentucky, have evaluated the need for further nitrogen oxide reductions from fossil-fueled plants to address interstate impacts. On August 23, 2018, Kentucky submitted a proposed state implementation plan finding that no additional reductions beyond existing and planned controls set forth in Kentucky's existing State Implementation Plan are necessary to prevent Kentucky from contributing significantly to any other state's nonattainment. On September 14, 2018, the EPA announced its denial of petitions filed by Maryland and Delaware alleging that the states including Kentucky and Pennsylvania contribute to nonattainment in the petitioning states. PPL, LKE, LG&E, and KU are unable to predict the outcome of ongoing and future evaluations by the EPA and the states, or whether such evaluations could potentially result in requirements for nitrogen oxide reductions beyond those currently required under the Cross-State Air Pollution Rule. Sulfur Dioxide In 2010, the EPA issued the current NAAQS for sulfur dioxide and required states to identify areas that meet those standards and areas that are in nonattainment. In July 2013, the EPA finalized nonattainment designations for parts of the country, including part of Jefferson County in Kentucky. As a result of scrubber replacements completed by LG&E at the Mill Creek plant in 2016, all Jefferson County monitors now indicate compliance with the sulfur dioxide standards. Additionally, LG&E accepted a new sulfur dioxide emission limit to ensure continuing compliance with the NAAQS. PPL, LKE, LG&E and KU do not anticipate any further measures to achieve compliance with the new sulfur dioxide standards. MATS On December 28, 2018, the EPA proposed to revise its previous finding that regulation of hazardous air emissions from coal- and oil-fired electric generating units is justified and instead find that the agency erred in determining such regulation is “appropriate and necessary” due to mistakes in its regulatory cost-benefit analysis. As a result of its review of relevant precedent, the EPA further proposed not to remove the coal- and oil-fired electric generating unit source category from the list of sources that must be regulated under Section 112 of the Clean Air Act and leave existing emission standards in place. Finally, the EPA proposed to find that the results of its residual risk and technology review indicate that residual risk due to air toxic emissions from this source category is acceptable and current standards provide an ample margin of safety to protect public health. LG&E and KU have completed installation of controls at their plants as necessary to achieve compliance with the applicable provision of MATS. It is not possible to predict the outcome of the pending regulatory proceedings including whether existing standards may be repealed, or the resulting impacts on plant operations, financial condition or results of operations. Climate Change There is continuing world-wide attention focused on issues related to climate change. In June 2016, President Obama announced that the United States, Canada and Mexico established the North American Climate, Clean Energy, and Environment Partnership Plan, which specifies actions to promote clean energy, address climate change and protect the environment. The plan includes a goal to provide 50% of the energy used in North America from clean energy sources by 2025. The plan does not impose any nation-specific requirements. In December 2015, 195 nations, including the U.S., signed the Paris Agreement on Climate, which establishes a comprehensive framework for the reduction of GHG emissions from both developed and developing nations. Although the agreement does not establish binding reduction requirements, it requires each nation to prepare, communicate, and maintain GHG reduction commitments. Reductions can be achieved in a variety of ways, including energy conservation, power plant efficiency improvements, reduced utilization of coal-fired generation or replacing coal-fired generation with natural gas or renewable generation. Based on the EPA's rules issued in 2015 imposing GHG emission standards for both new and existing power plants, the U.S. committed to an initial reduction target of 26% to 28% below 2005 levels by 2025. However, on June 1, 2017, President Trump announced a plan to withdraw from the Paris Agreement and undertake negotiations to reenter the current agreement or enter a new agreement on terms more favorable to the U.S. Under the terms of the Paris Agreement, any U.S. withdrawal would not be complete until November 2020. Additionally, the March 2017 Executive Order directed the EPA to review its 2015 greenhouse gas rules for consistency with certain policy directives and suspend, revise, or rescind those rules as appropriate. The March 2017 Executive Order also directs rescission of specified guidance, directives, and prior Presidential actions regarding climate change. PPL, LKE, LG&E and KU cannot predict the outcome of such regulatory actions or the impact, if any, on plant operations, rate treatment or future capital or operating needs. The U.K. has enacted binding carbon reduction requirements that are applicable to WPD. Under the U.K. law, WPD must purchase carbon allowances to offset emissions associated with WPD's operations. The cost of these allowances is not significant and is included in WPD's current operating expenses. The EPA's Rules under Section 111 of the Clean Air Act including the EPA's Proposed Affordable Clean Energy Rule In 2015 the EPA finalized rules imposing GHG emission standards for both new and existing power plants and had proposed a federal implementation plan that would apply to any states that failed to submit an acceptable state implementation plan to reduce GHG emissions on a state-by-state basis (the Clean Power Plan). Following legal challenges to the Clean Power Plan, a stay of those rules by the U.S. Supreme Court and the March 2017 Executive Order requiring the EPA to review the Clean Power Plan in October 2017, the EPA proposed to rescind the Clean Power Plan. On August 21, 2018, the EPA proposed the Affordable Clean Energy (ACE) Rule as a replacement for the Clean Power Plan pertaining to existing sources. The ACE Rule would give states broad latitude in establishing emission guidelines providing for plant-specific efficiency upgrades or "heat-rate improvements" that would reduce GHG emissions per unit of electricity generated. The ACE Rule proposes a list of "candidate technologies" that would be considered in establishing standards of performance at individual power plants. The ACE Rule also proposes new criteria for determining whether such efficiency projects would trigger New Source Review and thus be subject to more stringent emission controls. In April 2014, the Kentucky General Assembly passed legislation limiting the measures that the Kentucky Energy and Environment Cabinet may consider in setting performance standards to comply with the Clean Power Plan, if enacted. The legislation provides that such state GHG performance standards will be based on emission reductions, efficiency measures and other improvements available at each power plant, rather than renewable energy, end-use energy efficiency, fuel switching and re-dispatch. These statutory restrictions are broadly consistent with the EPA's proposed ACE Rule. LG&E and KU are monitoring developments at the state and federal level. Until the ACE Rule is finalized and the state determines implementation measures, PPL, LKE, LG&E and KU cannot predict the potential impact, if any, on plant operations, future capital or operating costs. PPL, LKE, LG&E and KU believe that the costs, which could be significant, would be subject to rate recovery. 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 June 2019. 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) CCRs In April 2015, the EPA published its final rule regulating CCRs. CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes. The rule became effective in October 2015. It imposes extensive new requirements, including location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements on CCR impoundments and landfills that are located on active power plants in the United States and not closed. Under the rule, CCRs are regulated as non-hazardous under Subtitle D of RCRA and beneficial use of CCRs is allowed, with some restrictions. The rule's requirements for covered CCR impoundments and landfills include implementation of groundwater monitoring and commencement or completion of closure activities generally between three and ten years from certain triggering events. The rule requires posting of compliance documentation on a publicly accessible website. Industry groups, environmental groups, individual companies and others have filed legal challenges to the final rule, which are pending before the D.C. Circuit Court of Appeals. On March 1, 2018, the EPA proposed amendments to the CCR rule primarily relating to impoundment closure and remediation requirements. On July 30, 2018, the EPA published in the Federal Register a final rule extending the deadline for closure of certain impoundments to October 2020 and adopting substantive changes relating to certifications, suspensions of groundwater monitoring and groundwater protection standards for certain constituents. The EPA has announced that additional amendments to the rule will be proposed. On August 21, 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR rule including provisions allowing unlined impoundments to continue operating and exempting inactive impoundments at inactive plants from regulation. PPL, LKE, LG&E and KU are unable to predict the outcome of the ongoing 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 matters, effective May 2017, aimed at reflecting the requirements of the federal CCR rule. In May 2017, a resident adjacent to LG&E's and KU's Trimble County plant filed a lawsuit in Franklin County, Kentucky Circuit Court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. On January 31, 2018, the state court issued an opinion invalidating certain procedural elements of the new rule but finding the substantive requirements of the new rule to be consistent with those of the federal CCR rule. This ruling was not appealed by any party to the litigation and is now final. Accordingly, LG&E and KU presently operate their facilities under continuing permits authorized via the former program and do not currently anticipate material im

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2018
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 service companies, the costs of these 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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194 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 revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of December 31, 2018 was $650 million . No balance was outstanding at December 31, 2018 and 2017. 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. In October 2018, the revolving line of credit was increased by $75 million to the current limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2018 and 2017 , $113 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2018 and 2017 were 3.85% and 2.87% . Interest expense on the revolving line of credit was not significant for 2018 , 2017 or 2016 . 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, 2018 and 2017 . 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 a $400 million ten -year-note with a PPL affiliate with an interest rate of 3.5% . At December 31, 2018 and 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $14 million for 2018 and 2017 and not significant for 2016 . In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028 with interest due in May and November. At December 31, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $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, 2018 and 2017 . (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, 2018 and 2017 . 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. For PPL Electric, see Note 13 for discussions regarding separation 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 service companies, the costs of these 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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194 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 revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of December 31, 2018 was $650 million . No balance was outstanding at December 31, 2018 and 2017. 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. In October 2018, the revolving line of credit was increased by $75 million to the current limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2018 and 2017 , $113 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2018 and 2017 were 3.85% and 2.87% . Interest expense on the revolving line of credit was not significant for 2018 , 2017 or 2016 . 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, 2018 and 2017 . 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 a $400 million ten -year-note with a PPL affiliate with an interest rate of 3.5% . At December 31, 2018 and 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $14 million for 2018 and 2017 and not significant for 2016 . In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028 with interest due in May and November. At December 31, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $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, 2018 and 2017 . (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, 2018 and 2017 . 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. For PPL Electric, see Note 13 for discussions regarding separation 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 service companies, the costs of these 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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194 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 revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of December 31, 2018 was $650 million . No balance was outstanding at December 31, 2018 and 2017. 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. In October 2018, the revolving line of credit was increased by $75 million to the current limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2018 and 2017 , $113 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2018 and 2017 were 3.85% and 2.87% . Interest expense on the revolving line of credit was not significant for 2018 , 2017 or 2016 . 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, 2018 and 2017 . 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 a $400 million ten -year-note with a PPL affiliate with an interest rate of 3.5% . At December 31, 2018 and 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $14 million for 2018 and 2017 and not significant for 2016 . In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028 with interest due in May and November. At December 31, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $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, 2018 and 2017 . (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, 2018 and 2017 . 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. For PPL Electric, see Note 13 for discussions regarding separation 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 service companies, the costs of these 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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194 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 revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of December 31, 2018 was $650 million . No balance was outstanding at December 31, 2018 and 2017. 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. In October 2018, the revolving line of credit was increased by $75 million to the current limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2018 and 2017 , $113 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2018 and 2017 were 3.85% and 2.87% . Interest expense on the revolving line of credit was not significant for 2018 , 2017 or 2016 . 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, 2018 and 2017 . 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 a $400 million ten -year-note with a PPL affiliate with an interest rate of 3.5% . At December 31, 2018 and 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $14 million for 2018 and 2017 and not significant for 2016 . In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028 with interest due in May and November. At December 31, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $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, 2018 and 2017 . (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, 2018 and 2017 . 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. For PPL Electric, see Note 13 for discussions regarding separation benefits.

Other Income (Expense) - net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2018
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL) The breakdown of "Other Income (Expense) - net" for the years ended December 31, was: 2018 2017 2016 Other Income Economic foreign currency exchange contracts (Note 17) $ 150 $ (261 ) $ 384 Defined benefit plans - non-service credits (Note 11) 257 167 112 Interest income 6 2 3 AFUDC - equity component 21 16 19 Miscellaneous 6 17 6 Total Other Income 440 (59 ) 524 2018 2017 2016 Other Expense Charitable contributions 24 8 9 Miscellaneous 20 21 13 Total Other Expense 44 29 22 Other Income (Expense) - net $ 396 $ (88 ) $ 502 (PPL Electric) The breakdown of "Other Income (Expense) - net" for the years ended December 31, was: 2018 2017 2016 Other Income Interest income $ 2 $ 1 $ 1 AFUDC - equity component 20 15 18 Defined benefit plans - non-service credits (Note 11) 5 1 3 Miscellaneous — — 2 Total Other Income 27 17 24 Other Expense Charitable contribution 3 2 2 Miscellaneous 1 3 2 Total Other Expense 4 5 4 Other Income (Expense) - net $ 23 $ 12 $ 20
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL) The breakdown of "Other Income (Expense) - net" for the years ended December 31, was: 2018 2017 2016 Other Income Economic foreign currency exchange contracts (Note 17) $ 150 $ (261 ) $ 384 Defined benefit plans - non-service credits (Note 11) 257 167 112 Interest income 6 2 3 AFUDC - equity component 21 16 19 Miscellaneous 6 17 6 Total Other Income 440 (59 ) 524 2018 2017 2016 Other Expense Charitable contributions 24 8 9 Miscellaneous 20 21 13 Total Other Expense 44 29 22 Other Income (Expense) - net $ 396 $ (88 ) $ 502 (PPL Electric) The breakdown of "Other Income (Expense) - net" for the years ended December 31, was: 2018 2017 2016 Other Income Interest income $ 2 $ 1 $ 1 AFUDC - equity component 20 15 18 Defined benefit plans - non-service credits (Note 11) 5 1 3 Miscellaneous — — 2 Total Other Income 27 17 24 Other Expense Charitable contribution 3 2 2 Miscellaneous 1 3 2 Total Other Expense 4 5 4 Other Income (Expense) - net $ 23 $ 12 $ 20

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2018
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, 2018 December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 621 $ 621 $ — $ — $ 485 $ 485 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 26 26 — — Special use funds (a) 59 59 — — — — — — Price risk management assets (b): Foreign currency contracts 202 — 202 — 163 — 163 — Cross-currency swaps 135 — 135 — 101 — 101 — Total price risk management assets 337 — 337 — 264 — 264 — Total assets $ 1,039 $ 702 $ 337 $ — $ 775 $ 511 $ 264 $ — December 31, 2018 December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Liabilities Price risk management liabilities (b): Interest rate swaps $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — Foreign currency contracts 2 — 2 — 148 — 148 — Total price risk management liabilities $ 22 $ — $ 22 $ — $ 174 $ — $ 174 $ — PPL Electric Assets Cash and cash equivalents $ 267 $ 267 $ — $ — $ 49 $ 49 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 269 $ 269 $ — $ — $ 51 $ 51 $ — $ — LKE Assets Cash and cash equivalents $ 24 $ 24 $ — $ — $ 30 $ 30 $ — $ — Total assets $ 24 $ 24 $ — $ — $ 30 $ 30 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — LG&E Assets Cash and cash equivalents $ 10 $ 10 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 10 $ 10 $ — $ — $ 15 $ 15 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — KU Assets Cash and cash equivalents $ 14 $ 14 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 14 $ 14 $ — $ — $ 15 $ 15 $ — $ — (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) 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. The funds are invested primarily 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, 2018 December 31, 2017 Carrying Fair Value Carrying Fair Value PPL $ 20,599 $ 22,939 $ 20,195 $ 23,783 PPL Electric 3,694 3,901 3,298 3,769 LKE 5,502 5,768 5,159 5,670 LG&E 1,809 1,874 1,709 1,865 KU 2,321 2,451 2,328 2,605 (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, 2018
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 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" interest rate and foreign currency derivatives with financial institutions, 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 $40 million and $20 million obligation to return cash collateral under master netting arrangements at December 31, 2018 and 2017 . PPL had no obligation to post cash collateral under master netting arrangements at December 31, 2018 and 2017 . LKE, LG&E and KU had no obligation to return cash collateral under master netting arrangements at December 31, 2018 and 2017 . LKE, LG&E and KU had no cash collateral posted under master netting arrangements at December 31, 2018 and 2017 . 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, 2018. For 2018 and 2017, PPL had no hedge ineffectiveness associated with interest rate derivatives. For 2016, hedge ineffectiveness associated with interest rate derivatives was insignificant. At December 31, 2018 , 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. For 2018, 2017 and 2016, PPL had no hedge ineffectiveness associated with cross-currency interest rate swap derivatives. 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 2018 and 2016, 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, 2018 , 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. In December 2016, a swap with a notional amount of $32 million was terminated. A cash settlement of $9 million was paid on the terminated swap. The settlement is included in noncurrent regulatory assets on the Balance Sheet and in "Cash Flows from Operating Activities" on the Statement of Cash Flows. At December 31, 2018 , 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, 2018 . At December 31, 2018 and 2017 , PPL had $31 million and $22 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, 2018 , the total exposure hedged by PPL was approximately £1.5 billion (approximately $2.2 billion based on contracted rates). These contracts had termination dates ranging from January 2019 through October 2020 . In the third quarter of 2016, PPL settled foreign currency hedges related to 2017 and 2018 anticipated earnings, resulting in receipt of $310 million of cash and entered into new hedges at current market rates. The notional amount of the settled hedges was approximately £1.3 billion (approximately $2.0 billion based on contracted rates) with termination dates from January 2017 through November 2018 . The settlement did not have a significant impact on net income as the hedge values were previously marked to fair value and recognized in "Other Income (Expense) - net" on the Statement of Income. 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, 2018 and 2017 . 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, 2018 December 31, 2017 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) 6 — — — 4 — — — Foreign currency contracts — — 103 2 — — 45 67 Total current 6 — 103 6 4 — 45 71 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 16 — — — 22 Cross-currency swaps (b) 129 — — — 97 — — — Foreign currency contracts — — 99 — — — 118 81 Total noncurrent 129 — 99 16 97 — 118 103 Total derivatives $ 135 $ — $ 202 $ 22 $ 101 $ — $ 163 $ 174 (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 (Effective Portion) Location of Gain (Loss) Recognized in Income on Derivative Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing) 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 2016 Cash Flow Hedges: Interest rate swaps $ (21 ) Interest Expense $ (7 ) $ — Cross-currency swaps 130 Other Income (Expense) - net 116 — Interest Expense 3 — Total $ 109 $ 112 $ — Net Investment Hedges: Foreign currency contracts $ 2 Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized in Income on Derivative 2018 2017 2016 Foreign currency contracts Other Income (Expense) - net $ 150 $ (261 ) $ 384 Interest rate swaps Interest Expense (5 ) (6 ) (7 ) Total $ 145 $ (267 ) $ 377 Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets 2018 2017 2016 Interest rate swaps Regulatory assets - noncurrent $ 6 $ 5 $ 7 (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, 2018 December 31, 2017 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 — 16 — 22 Total noncurrent — 16 — 22 Total derivatives $ — $ 20 $ — $ 26 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) 2018 2017 2016 Interest rate swaps Interest Expense $ (5 ) $ (6 ) $ (7 ) Derivative Instruments Location of Gain (Loss) 2018 2017 2016 Interest rate swaps Regulatory assets - noncurrent $ 6 $ 5 $ 7 (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, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20 December 31, 2017 Treasury Derivatives PPL $ 264 $ 107 $ 20 $ 137 $ 174 $ 107 $ — $ 67 LKE — — — — 26 — — 26 LG&E — — — — 26 — — 26 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, 2018 , 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 $ 6 $ 6 $ 6 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) 6 6 6 (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, 2018
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 2018 2017 2018 2017 2018 2017 2018 2017 Balance at beginning of period (a) $ 2,596 $ 2,398 $ 662 $ 662 $ — $ — $ 3,258 $ 3,060 Effect of foreign currency exchange rates (149 ) 198 — — — — (149 ) 198 Goodwill recognized during the period (b) — — — — 53 — 53 — Balance at end of period (a) $ 2,447 $ 2,596 $ 662 $ 662 $ 53 $ — $ 3,162 $ 3,258 (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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Contracts (a) $ 137 $ 75 $ 138 $ 67 Land rights and easements 418 128 382 120 Licenses and other 21 1 8 3 Total subject to amortization 576 204 528 190 Not subject to amortization due to indefinite life: Land rights and easements 339 — 359 — Other 6 — — — Total not subject to amortization due to indefinite life 345 — 359 — Total $ 921 $ 204 $ 887 $ 190 (a) Gross carrying amount in 2018 and 2017 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: 2018 2017 2016 Intangible assets with no regulatory offset $ 7 $ 6 $ 6 Intangible assets with regulatory offset 8 9 24 Total $ 15 $ 15 $ 30 Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 Intangible assets with no regulatory offset $ 7 $ 7 $ 7 $ 7 $ 7 Intangible assets with regulatory offset 9 8 8 8 8 Total $ 16 $ 15 $ 15 $ 15 $ 15 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 363 $ 121 $ 361 $ 117 Licenses and other 2 1 3 1 Total subject to amortization 365 122 364 118 Not subject to amortization due to indefinite life: Land rights and easements 17 — 13 — Total $ 382 $ 122 $ 377 $ 118 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was insignificant in 2018 , 2017 and 2016 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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 21 $ 3 $ 21 $ 3 OVEC power purchase agreement (a) 126 66 126 58 Total subject to amortization $ 147 $ 69 $ 147 $ 61 (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: 2018 2017 2016 Intangible assets with no regulatory offset $ — $ — $ 1 Intangible assets with regulatory offset 8 9 24 Total $ 8 $ 9 $ 25 Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 Intangible assets with regulatory offset $ 9 $ 8 $ 8 $ 8 $ 8 (LG&E) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2018 December 31, 2017 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) 87 46 87 40 Total subject to amortization $ 94 $ 47 $ 94 $ 41 (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: 2018 2017 2016 Intangible assets with regulatory offset $ 6 $ 6 $ 13 Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 14 $ 2 $ 14 $ 2 OVEC power purchase agreement (a) 39 20 39 18 Total subject to amortization $ 53 $ 22 $ 53 $ 20 (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: 2018 2017 2016 Intangible assets with no regulatory offset $ — $ — $ 1 Intangible assets with regulatory offset 2 3 11 Total $ 2 $ 3 $ 12 Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 Intangible assets with regulatory offset $ 3 $ 2 $ 2 $ 2 $ 2

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2018
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) LKE, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 13 for information on the CCR rule. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. 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. As described in Notes 1 and 7 , 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 2018 2017 2018 2017 2018 2017 2018 2017 ARO at beginning of period $ 397 $ 488 $ 356 $ 433 $ 121 $ 145 $ 235 $ 288 Accretion 20 21 18 20 6 7 12 13 Obligations incurred 8 — 8 — — — 8 — Changes in estimated timing or cost (3 ) (73 ) (14 ) (54 ) (2 ) (8 ) (12 ) (46 ) Effect of foreign currency exchange rates (3 ) 4 — — — — — — Obligations settled (72 ) (43 ) (72 ) (43 ) (22 ) (23 ) (50 ) (20 ) ARO at end of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2018
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, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the year (1,107 ) 91 — (3 ) (61 ) (1,080 ) Reclassifications from AOCI — (91 ) (1 ) 1 121 30 Net OCI during the year (1,107 ) — (1 ) (2 ) 60 (1,050 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) 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 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 ) 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 ) LKE December 31, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the year — — (27 ) (27 ) Reclassifications from AOCI (1 ) 2 2 3 Net OCI during the year (1 ) 2 (25 ) (24 ) 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 ) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2018 , 2017 and 2016 . LKE amounts are insignificant for the years ended December 31, 2018 , 2017 and 2016 . 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 2018 2017 2016 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (8 ) $ (9 ) $ (7 ) Interest Expense Cross-currency swaps 42 (82 ) 116 Other Income (Expense) - net 1 — 3 Interest Expense Total Pre-tax 35 (91 ) 112 Income Taxes (6 ) 18 (21 ) Total After-tax 29 (73 ) 91 Equity Investees' AOCI — (1 ) 1 Other Income (Expense) - net Total Pre-tax — (1 ) 1 Income Taxes — — — Total After-tax — (1 ) 1 Defined benefit plans Prior service costs (2 ) (2 ) (2 ) Net actuarial loss (178 ) (167 ) (156 ) Total Pre-tax (180 ) (169 ) (158 ) Income Taxes 36 38 36 Total After-tax (144 ) (131 ) (122 ) Total reclassifications during the year $ (115 ) $ (205 ) $ (30 )
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, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the year (1,107 ) 91 — (3 ) (61 ) (1,080 ) Reclassifications from AOCI — (91 ) (1 ) 1 121 30 Net OCI during the year (1,107 ) — (1 ) (2 ) 60 (1,050 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) 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 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 ) 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 ) LKE December 31, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the year — — (27 ) (27 ) Reclassifications from AOCI (1 ) 2 2 3 Net OCI during the year (1 ) 2 (25 ) (24 ) 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 ) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2018 , 2017 and 2016 . LKE amounts are insignificant for the years ended December 31, 2018 , 2017 and 2016 . 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 2018 2017 2016 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (8 ) $ (9 ) $ (7 ) Interest Expense Cross-currency swaps 42 (82 ) 116 Other Income (Expense) - net 1 — 3 Interest Expense Total Pre-tax 35 (91 ) 112 Income Taxes (6 ) 18 (21 ) Total After-tax 29 (73 ) 91 Equity Investees' AOCI — (1 ) 1 Other Income (Expense) - net Total Pre-tax — (1 ) 1 Income Taxes — — — Total After-tax — (1 ) 1 Defined benefit plans Prior service costs (2 ) (2 ) (2 ) Net actuarial loss (178 ) (167 ) (156 ) Total Pre-tax (180 ) (169 ) (158 ) Income Taxes 36 38 36 Total After-tax (144 ) (131 ) (122 ) Total reclassifications during the year $ (115 ) $ (205 ) $ (30 )

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Guidance Pending Adoption	(All Registrants) Accounting for Leases In February 2016, the Financial Accounting Standards Board (FASB) issued accounting guidance for leases. This new guidance requires lessees to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that 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 will result in straight-line expense (similar to current operating leases) while finance leases will result in a front-loaded expense pattern (similar to current capital leases). Classification will be based on criteria that are largely similar to those applied in current lease accounting, but without explicit bright line tests. The Registrants currently do not have any finance 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 the new revenue recognition standard. Similar to current practice, lessors will classify leases as operating, direct financing, or sales-type. The Registrants currently do not have significant lessor activity. The Registrants adopted this standard on January 1, 2019 using a modified retrospective transition method with transition applied as of the beginning of the period of adoption. Additionally, the Registrants have elected the following practical expedients: • For existing leases, the Registrants did not re-assess whether those contracts contain leases, retained existing lease classifications and did not reassess initial direct costs. • The Registrants did not evaluate land easements that were not previously accounted for as leases under this new guidance. Land easements are evaluated under this new guidance beginning January 1, 2019. Key implementation activities have been completed, which included compiling the lease inventory, concluding on industry issues and implementing controls over the new requirements to record operating leases on the balance sheet. The Registrants are expecting amounts recorded on the balance sheet at adoption to be approximately: PPL LKE LGE KU Right of Use Asset $ 80 $ 55 $ 25 $ 30 Current Lease Liability 25 20 10 10 Noncurrent Lease Liability 65 45 15 25 The Registrants’ are expecting no impact to the Statements of Cash Flows or Statements of Income. The Registrants will also provide additional disclosures around the nature of the leasing activities beginning in the Form 10-Q for the period ended March 31, 2019. These include additional qualitative disclosures, such as a general description of leases, and quantitative disclosures, such as lease costs, weighted average remaining lease term and weighted average discount rate. 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. For public business entities, this guidance will be applied using a modified retrospective approach and is effective for fiscal years beginning after December 15, 2019, and interim periods within those years. All entities may early adopt this guidance beginning after December 15, 2018, including interim periods within those years. The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it. Improvements to Accounting for Hedging Activities In August 2017, the FASB issued accounting guidance that reduces complexity when applying hedge accounting as well as improves transparency about an entity's risk management activities. This guidance eliminates recognizing hedge ineffectiveness for cash flow and net investment hedges and provides for the ability to perform subsequent effectiveness assessments qualitatively. The guidance also makes certain changes to allowable methodologies such as allowing 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. For public business entities, this guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted. This standard must be adopted using a modified retrospective approach and provides for certain transition elections that must be made prior to the first effectiveness testing date after adoption. The Registrants will also provide additional disclosures around the income statement impacts of hedging activities as well as remove disclosures related to ineffectiveness in the Form 10-Q for the period ended March 31, 2019. Other impacts of adopting this guidance are not expected to be material. The Registrants adopted this guidance effective January 1, 2019. 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. For public business entities, this guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted. This standard must be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption. The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it. 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. For public business entities, this guidance will be applied prospectively and is effective for annual or any interim goodwill impairment tests for fiscal years beginning after December 15, 2019. All entities may early adopt this guidance for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it.

SCHEDULE I - CONDENSED UNCONSOL

SCHEDULE I - CONDENSED UNCONSOLICATED FINANCIAL STATEMENTS AND NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS	12 Months Ended
	Dec. 31, 2018
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) 2018 2017 2016 Other Income (Expense) - net Equity in Earnings of Subsidiaries $ 470 $ 397 $ 452 Interest Income with Affiliate 25 14 9 Total 495 411 461 Interest Expense 29 30 29 Interest Expense with Affiliate 28 20 18 Income Before Income Taxes 438 361 414 Income Tax Expense (Benefit) (7 ) 45 (15 ) Net Income $ 445 $ 316 $ 429 Total other comprehensive income (loss) 17 (18 ) (24 ) Comprehensive Income Attributable to Member $ 462 $ 298 $ 405 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) 2018 2017 2016 Cash Flows from Operating Activities Net cash provided by (used in) operating activities $ 346 $ 401 $ 285 Cash Flows from Investing Activities Capital contributions to affiliated subsidiaries (128 ) (30 ) (91 ) Net decrease (increase) in notes receivable from affiliates (26 ) (28 ) 47 Net cash provided by (used in) investing activities (154 ) (58 ) (44 ) Cash Flows from Financing Activities Net increase (decrease) in notes payable with affiliates 110 58 90 Net increase (decrease) in short-term debt — — (75 ) Contribution from member — — 61 Distribution to member (302 ) (402 ) (316 ) Net cash provided by (used in) financing activities (192 ) (344 ) (240 ) Net Increase (Decrease) in Cash and Cash Equivalents — (1 ) 1 Cash and Cash Equivalents at Beginning of Period — 1 — Cash and Cash Equivalents at End of Period $ — $ — $ 1 Supplemental disclosures of cash flow information: Cash Dividends Received from Subsidiaries $ 402 $ 418 $ 376 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) 2018 2017 Assets Current Assets Accounts receivable $ — $ 1 Accounts receivable from affiliates — 8 Income taxes receivable — 1 Notes receivable from affiliates 1,061 1,035 Total Current Assets 1,061 1,045 Investments Affiliated companies at equity 5,422 5,209 Other Noncurrent Assets Deferred income taxes 299 263 Total Assets $ 6,782 $ 6,517 Liabilities and Equity Current Liabilities Notes payable to affiliates $ 177 $ 241 Accounts payable to affiliates 487 469 Taxes 11 35 Other current liabilities 6 5 Total Current Liabilities 681 750 Long-term Debt Long-term debt 723 722 Notes payable to affiliates 650 476 Total Long-term Debt 1,373 1,198 Deferred Credits and Other Noncurrent Liabilities 5 6 Equity 4,723 4,563 Total Liabilities and Equity $ 6,782 $ 6,517 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, 2018
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 2018 Operating revenues $ 2,126 $ 1,848 $ 1,872 $ 1,939 Operating income 851 658 686 657 Net income (e) 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 Dividends declared per share of common stock (d) 0.41 0.41 0.41 0.41 2017 Operating revenues $ 1,951 $ 1,725 $ 1,845 $ 1,926 Operating income (c) 758 658 736 749 Net income (e) 403 292 355 78 Net income available to PPL common shareowners: (b) Basic EPS 0.59 0.43 0.52 0.11 Diluted EPS 0.59 0.43 0.51 0.11 Dividends declared per share of common stock (d) 0.395 0.395 0.395 0.395 (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. (c) 2017 reflects the retrospective application of new accounting guidance related to the income statement presentation of net periodic benefit costs adopted by PPL in January 2018. See Note 1 to the Financial Statements for additional information on the adoption of this guidance. (d) PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors. (e) Increases in net income for the quarter ended June 30, 2018 compared with June 30, 2017 were primarily due to the favorable impact of foreign currency economic hedges. Increases in net income for the quarter ended December 31, 2018 compared with December 31, 2017 were primarily due to the favorable impact of foreign currency economic hedges in 2018 and the unfavorable impact of U.S. tax reform in 2017.
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 2018 Operating revenues $ 639 $ 517 $ 548 $ 573 Operating income 228 133 178 155 Net income 148 75 111 96 2017 Operating revenues $ 573 $ 500 $ 547 $ 575 Operating income 160 155 189 196 Net income 79 77 95 111 (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, 2018
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 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 costs that are expected to be incurred in the future, 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 the uncertain future events and (2) the amount of the 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 that would 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 the 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. 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.
Revenue Recognition	Revenue Recognition (All Registrants) Operating revenues are primarily recorded based on energy deliveries through the end of the 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 rates in the future as a result of 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 an increase or reduction in 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 will allow future base demand revenues agreed with the regulator 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 they are billed to customers, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising for the periods beginning with the 2014/15 regulatory year and refunded/recovered under RIIO-ED1 are refunded/recovered on a two year lag (previously one year ). Therefore the 2015/16 over/under-recovery adjustment occurred in the 2017/18 regulatory year.
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 collectability 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. (PPL) Investments in Debt Securities Investments in debt securities are classified as held-to-maturity and measured at amortized cost when there is an intent and ability to hold the securities to maturity. Debt securities held principally to capitalize on fluctuations in their value with the intention of selling them in the near-term are classified as trading. All other investments in debt securities are classified as available-for-sale. Both trading and available-for-sale securities are carried at fair value. The specific identification method is used to calculate realized gains and losses on debt securities. Unrealized gains and losses on available-for-sale debt securities are reported in other comprehensive income until realized. The criteria for determining whether a decline in fair value of a debt security is other than temporary and whether the other-than-temporary impairment is recognized in earnings or reported in OCI require that when a debt security is in an unrealized loss position and: • there is an intent or a requirement to sell the security before recovery, the other-than-temporary impairment is recognized currently in earnings; or • there is no intent or requirement to sell the security before recovery, the portion of the other-than-temporary impairment that is considered a credit loss is recognized currently in earnings and the remainder of the other-than-temporary impairment is reported in OCI, net of tax; or • there is no intent or requirement to sell the security before recovery and there is no credit loss, the unrealized loss is reported in OCI, net of tax. (PPL, LKE, LG&E and KU) Investments in Equity Securities LG&E and KU each have an investment in OVEC, which is recorded at cost. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU are responsible for a pro-rata share of certain OVEC obligations, pursuant to their power purchase contract with OVEC. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting regulatory liability, both of which are being amortized using the units-of-production method until March 2026. For information relating to the bankruptcy filing of a co-sponsor of OVEC and potential impact, see footnote (f) under “Guarantees and Other Assurances” in Note 13. See also Notes 7 , 13 and 18 for additional discussion of the power purchase agreement.
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. 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 the costs are incurred. No costs associated with planned major maintenance projects are accrued to PP&E in advance of the period in which the work is performed. 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. 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, except for certain instances in KU's FERC approved rates charged to its municipal customers, as a return is provided on construction work in progress. (PPL) PPL capitalizes interest costs as part of construction costs. 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.
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, LKE, LG&E and KU elected to bypass the qualitative step zero evaluation of goodwill and quantitatively tested the goodwill of all reporting units for impairment as of the fourth quarter of 2018. 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 expected average remaining service of active plan participants. 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 expected average remaining service period of active plan participants. In selecting the discount rates for U.S. defined benefit plans, the plan sponsors start with a cash flow analysis of the expected benefit payment stream for their plans. The plan-specific cash flows are matched against the coupons and expected maturity values of individually selected bonds. This bond matching process begins with the full universe of Aa-rated non-callable (or callable with make-whole provisions) bonds, serving as the base from which those with the lowest and highest yields are eliminated to develop an appropriate subset of bonds. Individual bonds are then selected based on the timing of each plan's cash flows and parameters are established as to the percentage of each individual bond issue that could be hypothetically purchased and the surplus reinvestment rates to be assumed. In selecting the discount rate for its U.K. pension plans, WPD starts with a cash flow analysis of the expected benefit payment stream for its plans. These plan-specific cash flows are matched against a spot-rate yield curve to determine the assumed discount rate. The spot-rate yield curve uses an iBoxx British pounds sterling denominated corporate bond index as its base. From this base, those bonds with the lowest and highest yields are eliminated to develop an appropriate subset of bonds. WPD uses the single weighted-average discount rate derived from the spot rates to discount the benefit obligation. In addition, the spot rates that match the cash flows associated with the service cost and interest cost are used to discount those components of net periodic defined benefit cost. 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. The Registrants recognized certain provisional amounts relating to the impact of the enactment of the TCJA in their December 31, 2017 financial statements, in accordance with SEC guidance. Included in those provisional amounts were estimates of: tax depreciation, deductible executive compensation, accumulated foreign earnings, foreign tax credits, and deemed dividends from foreign subsidiaries, all of which were based on the interpretation and application of various provisions of the TCJA. In the third quarter of 2018, PPL filed its consolidated federal income tax return, which was prepared using guidance issued by the U.S. Treasury Department and the IRS since the filing of each Registrant's 2017 Form 10-K. Accordingly, the Registrants have updated the following provisional amounts and now consider them to be complete: (1) the amount of the deemed dividend and associated foreign tax credits relating to the transition tax imposed on accumulated foreign earnings as of December 31, 2017; (2) the amount of accelerated 100% "bonus" depreciation PPL was eligible to claim in its 2017 federal income tax return; and (3) the related impacts on PPL's 2017 consolidated federal net operating loss to be carried forward to future periods. In addition, the Registrants recorded the tax impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on the changes to deferred tax assets and liabilities resulting from the completed provisional amounts. The completed provisional amounts related to the tax rate reduction had an insignificant impact on the net regulatory liabilities of PPL's U.S. regulated operations. In the fourth quarter of 2018, PPL completed its analysis of the deductibility of executive compensation awarded as of November 2, 2017 and concluded that no material change to the provisional amounts is required. See Note 6 to the Financial Statements for the final amounts reported in PPL's 2017 federal income tax return, provisional adjustment amounts for the year ended December 31, 2017, the related measurement period adjustments and the resulting tax impact for 2018. The Registrants' accounting related to the effects of the TCJA on financial results for the period ended December 31, 2017 is complete as of December 31, 2018 with respect to all provisional amounts. In 2018, the IRS issued proposed regulations for certain provisions of the TCJA, including interest deductibility, Base Erosion Anti-Avoidance Tax (BEAT), and Global Intangible Low-Taxed Income (GILTI). PPL has determined that the proposed regulations related to BEAT and GILTI do not materially change PPL's current interpretation of the statutory impact of these rules on the company. Proposed regulations relating to the limitation on the deductibility of interest expense were issued in November 2018 and such regulations provide detailed rules implementing the broader statutory provisions. These proposed regulations should not apply to the Registrants until the year in which the regulations are issued in final form, which is expected to be 2019. It is uncertain what form the final regulations will take and, therefore, the Registrants cannot predict what impact the final regulations will have on the tax deductibility of interest expense. However, if the proposed regulations were issued as final in their current form, the Registrants could have a limitation on a portion of their interest expense deduction for tax purposes and such limitation could be significant. Significant management judgment is also 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. Additionally, significant management judgment is also required to determine the amount of benefit to be recognized in relation to an uncertain tax position. 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% . 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. 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 Registrants consider the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies in initially recording and subsequently reevaluating the need for valuation allowances. 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 Registrants defer investment tax credits when the credits are utilized 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 other comprehensive income or loss 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 pre-tax income 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 electric 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 clause 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.
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) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.
LG And E And KU Energy LLC [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, LG&E and KU. LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name.
Investments	Investments in Equity Securities LG&E and KU each have an investment in OVEC, which is recorded at cost. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU are responsible for a pro-rata share of certain OVEC obligations, pursuant to their power purchase contract with OVEC. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting regulatory liability, both of which are being amortized using the units-of-production method until March 2026. For information relating to the bankruptcy filing of a co-sponsor of OVEC and potential impact, see footnote (f) under “Guarantees and Other Assurances” in Note 13. See also Notes 7 , 13 and 18 for additional discussion of the power purchase agreement.
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.
Investments	Investments in Equity Securities LG&E and KU each have an investment in OVEC, which is recorded at cost. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU are responsible for a pro-rata share of certain OVEC obligations, pursuant to their power purchase contract with OVEC. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting regulatory liability, both of which are being amortized using the units-of-production method until March 2026. For information relating to the bankruptcy filing of a co-sponsor of OVEC and potential impact, see footnote (f) under “Guarantees and Other Assurances” in Note 13. See also Notes 7 , 13 and 18 for additional discussion of the power purchase agreement.
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.
Investments	Investments in Equity Securities LG&E and KU each have an investment in OVEC, which is recorded at cost. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU are responsible for a pro-rata share of certain OVEC obligations, pursuant to their power purchase contract with OVEC. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting regulatory liability, both of which are being amortized using the units-of-production method until March 2026. For information relating to the bankruptcy filing of a co-sponsor of OVEC and potential impact, see footnote (f) under “Guarantees and Other Assurances” in Note 13. See also Notes 7 , 13 and 18 for additional discussion of the power purchase agreement.
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.

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2018
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, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 that would 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 the 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. 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.
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, 2018
Summary of Significant Accounting Policies [Line Items]
Schedule of Utility Revenue	For the years ended December 31, the Statements of Income "Operating Revenues" line item contains revenue from the following: 2018 2017 2016 Domestic electric and gas revenues (a) $ 5,491 $ 5,351 $ 5,297 U.K. operating revenues (b) 2,268 2,091 2,207 Domestic - other 26 5 13 Total $ 7,785 $ 7,447 $ 7,517 (a) Represents revenues from cost-based rate-regulated generation, transmission and/or distribution in Pennsylvania, Kentucky and Virginia, including regulated wholesale revenue. (b) Primarily represents regulated electricity distribution revenues from the operation of WPD's distribution networks.
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 2018 $ 51 $ 41 $ 3 $ 39 $ 56 2017 54 28 (1 ) 30 51 2016 41 44 — 31 54 PPL Electric 2018 $ 24 $ 29 $ — $ 26 $ 27 2017 28 18 — 22 24 2016 16 35 — 23 28 LKE 2018 $ 25 $ 10 $ 3 $ 11 $ 27 2017 24 8 (1 ) 6 25 2016 23 8 — 7 24 LG&E 2018 $ 1 $ 4 $ 1 $ 5 $ 1 2017 2 2 (1 ) 2 1 2016 1 2 1 2 2 KU 2018 $ 1 $ 5 $ 2 $ 6 $ 2 2017 2 4 (1 ) 4 1 2016 2 4 — 4 2 (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: 2018 2017 2016 PPL 2.77 % 2.65 % 2.73 % PPL Electric 3.01 % 2.86 % 2.63 % LKE 3.69 % 3.64 % 3.69 % LG&E 3.63 % 3.63 % 3.58 % KU 3.74 % 3.66 % 3.77 %
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: PPL LKE LG&E KU 2018 2017 2018 2017 2018 2017 2018 2017 Fuel $ 98 $ 107 $ 98 $ 107 $ 42 $ 45 $ 56 $ 62 Natural gas stored underground 41 43 41 43 41 43 — — Materials and supplies 164 170 109 104 44 43 65 61 Total $ 303 $ 320 $ 248 $ 254 $ 127 $ 131 $ 121 $ 123
Schedule of Non-Service Benefits Costs (Credits)	The following provides the non-service cost components of net periodic benefits (costs) or credits presented in "Other Income (Expense) - net" in 2018 and reclassified from "Other operation and maintenance" to "Other Income (Expense) - net" in 2017 and 2016 on the Statements of Income as a result of the adoption. 2018 2017 2016 PPL $ 257 $ 167 $ 112 PPL Electric 5 1 3 LKE 4 (5 ) (6 ) LG&E (2 ) (5 ) (5 ) KU 3 (1 ) (2 )
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 $ 621 $ 485 $ 267 $ 49 Restricted cash - current 3 3 2 2 Restricted cash - noncurrent (a) 19 23 — — Total Cash, Cash Equivalents and Restricted Cash $ 643 $ 511 $ 269 $ 51 (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: 2018 2017 PPL Electric $ 19 $ 61 LKE (16 ) (23 ) LG&E — — KU (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 $ 621 $ 485 $ 267 $ 49 Restricted cash - current 3 3 2 2 Restricted cash - noncurrent (a) 19 23 — — Total Cash, Cash Equivalents and Restricted Cash $ 643 $ 511 $ 269 $ 51 (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]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2018 2017 PPL Electric $ 19 $ 61 LKE (16 ) (23 ) LG&E — — KU (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 2018 2017 2018 2017 2018 2017 2018 2017 Fuel $ 98 $ 107 $ 98 $ 107 $ 42 $ 45 $ 56 $ 62 Natural gas stored underground 41 43 41 43 41 43 — — Materials and supplies 164 170 109 104 44 43 65 61 Total $ 303 $ 320 $ 248 $ 254 $ 127 $ 131 $ 121 $ 123
Louisville Gas And Electric Co [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2018 2017 PPL Electric $ 19 $ 61 LKE (16 ) (23 ) LG&E — — KU (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 2018 2017 2018 2017 2018 2017 2018 2017 Fuel $ 98 $ 107 $ 98 $ 107 $ 42 $ 45 $ 56 $ 62 Natural gas stored underground 41 43 41 43 41 43 — — Materials and supplies 164 170 109 104 44 43 65 61 Total $ 303 $ 320 $ 248 $ 254 $ 127 $ 131 $ 121 $ 123
Kentucky Utilities Co [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2018 2017 PPL Electric $ 19 $ 61 LKE (16 ) (23 ) LG&E — — KU (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 2018 2017 2018 2017 2018 2017 2018 2017 Fuel $ 98 $ 107 $ 98 $ 107 $ 42 $ 45 $ 56 $ 62 Natural gas stored underground 41 43 41 43 41 43 — — Materials and supplies 164 170 109 104 44 43 65 61 Total $ 303 $ 320 $ 248 $ 254 $ 127 $ 131 $ 121 $ 123

Segment and Related Informati_2

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2018
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: 2018 2017 2016 Operating Revenues from external customers (a) U.K. Regulated $ 2,268 $ 2,091 $ 2,207 Kentucky Regulated 3,214 3,156 3,141 Pennsylvania Regulated 2,277 2,195 2,156 Corporate and Other 26 5 13 Total $ 7,785 $ 7,447 $ 7,517 Depreciation U.K. Regulated $ 247 $ 230 $ 233 Kentucky Regulated 475 439 404 Pennsylvania Regulated 352 309 253 Corporate and Other 20 30 36 Total $ 1,094 $ 1,008 $ 926 Amortization (b) U.K. Regulated $ 34 $ 34 $ 16 Kentucky Regulated 18 24 29 Pennsylvania Regulated 22 33 32 Corporate and Other 4 6 3 Total $ 78 $ 97 $ 80 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ (190 ) $ 166 $ 13 Kentucky Regulated 6 6 6 Corporate and Other (2 ) 6 — Total $ (186 ) $ 178 $ 19 Interest Expense U.K. Regulated $ 413 $ 397 $ 402 Kentucky Regulated 274 261 260 Pennsylvania Regulated 159 142 129 Corporate and Other 117 101 97 Total $ 963 $ 901 $ 888 Income Before Income Taxes U.K. Regulated $ 1,339 $ 804 $ 1,479 Kentucky Regulated 531 645 640 Pennsylvania Regulated 567 575 550 Corporate and Other (152 ) (112 ) (119 ) Total $ 2,285 $ 1,912 $ 2,550 2018 2017 2016 Income Taxes (d) U.K. Regulated $ 225 $ 152 $ 233 Kentucky Regulated 120 359 242 Pennsylvania Regulated 136 216 212 Corporate and Other (23 ) 57 (39 ) Total $ 458 $ 784 $ 648 Deferred income taxes and investment tax credits (e) U.K. Regulated $ 118 $ 66 $ 31 Kentucky Regulated 94 294 291 Pennsylvania Regulated 125 257 221 Corporate and Other 18 90 17 Total $ 355 $ 707 $ 560 Net Income U.K. Regulated $ 1,114 $ 652 $ 1,246 Kentucky Regulated 411 286 398 Pennsylvania Regulated 431 359 338 Corporate and Other (129 ) (169 ) (80 ) Total $ 1,827 $ 1,128 $ 1,902 (a) See Note 1 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of 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: 2018 2017 2016 Expenditures for long-lived assets U.K. Regulated $ 954 $ 1,015 $ 1,031 Kentucky Regulated 1,117 892 791 Pennsylvania Regulated 1,196 1,254 1,134 Corporate and Other 1 10 1 Total $ 3,268 $ 3,171 $ 2,957 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2018 2017 Total Assets U.K. Regulated (a) $ 16,700 $ 16,813 Kentucky Regulated 15,078 14,468 Pennsylvania Regulated 11,257 10,082 Corporate and Other (b) 361 116 Total $ 43,396 $ 41,479 (a) Includes $12.4 billion and $12.5 billion of net PP&E as of December 31, 2018 and December 31, 2017 . 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: 2018 2017 2016 Revenues from external customers U.K. $ 2,268 $ 2,091 $ 2,207 U.S. 5,517 5,356 5,310 Total $ 7,785 $ 7,447 $ 7,517
Long-lived Assets	Geographic data for the years ended December 31 are as follows: As of December 31, 2018 2017 Long-Lived Assets U.K. $ 12,791 $ 12,851 U.S. 22,384 20,936 Total $ 35,175 $ 33,787

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Dec. 31, 2018
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 year ended December 31: 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) PPL includes $2.3 billion for the year ended December 31, 2018 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 for PPL Electric include the over/under-collection of its transmission formula rate. Alternative revenue programs for LKE, LG&E and KU include the over/under collection for the ECR and DSM programs as well as LG&E's over/under collection of its GLT program and KU's over/under collection of its generation formula rate. Over-collections of revenue are shown as positive amounts in the table above; under-collections are 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 year ended December 31: 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.
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: 2018 PPL $ 34 PPL Electric 24 LKE 9 LG&E 4 KU 5
Contract with Customer, Asset and Liability [Table Text Block]	The following table shows the balances of contract liabilities resulting from contracts with customers. PPL PPL Electric LKE LG&E KU Contract liabilities as of December 31, 2017 $ 29 $ 19 $ 8 $ 4 $ 4 Contract liabilities as of December 31, 2018 42 23 9 5 4
Contract With Customer Liability Revenue Recognized [Table Text Block]	The following table shows the revenue recognized in 2018 that was included in the contract liability balance at the beginning of the year. 2018 PPL $ 21 PPL Electric 8 LKE 8 LG&E 4 KU 4

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2018
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: 2018 2017 2016 Income (Numerator) Net income $ 1,827 $ 1,128 $ 1,902 Less amounts allocated to participating securities 2 2 6 Net income available to PPL common shareowners - Basic and Diluted $ 1,825 $ 1,126 $ 1,896 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 704,439 685,240 677,592 Add incremental non-participating securities: Share-based payment awards (a) 445 2,094 2,854 Forward sale agreements 3,735 — — Weighted-average shares - Diluted EPS 708,619 687,334 680,446 Basic EPS Net Income available to PPL common shareowners $ 2.59 $ 1.64 $ 2.80 Diluted EPS Net Income available to PPL common shareowners $ 2.58 $ 1.64 $ 2.79 (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): 2018 Stock-based compensation plans (a) 720 DRIP 1,974 (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: 2018 2017 2016 Stock options 172 696 696 Performance units — — 176 Restricted stock units 11 — —

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Taxes [Line Items]
Tax Reform	The final amounts reported in PPL's 2017 federal income tax return, provisional amounts for the year ended December 31, 2017, the related measurement period adjustments, and the resulting tax impact for the year ended December 31,2018 are as follows. Taxable Income (Loss) (a) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 397 $ 462 $ (65 ) Bonus Depreciation (b) (67 ) — (67 ) Consolidated Federal Net Operating Loss due to the TCJA (c) (330 ) (462 ) 132 Total $ — $ — $ — PPL Electric Bonus Depreciation (b) $ (39 ) $ — $ (39 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (68 ) (105 ) 37 Total $ (107 ) $ (105 ) $ (2 ) LKE Bonus Depreciation (b) $ (28 ) $ — $ (28 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (32 ) (45 ) 13 Total $ (60 ) $ (45 ) $ (15 ) LG&E Bonus Depreciation (b) $ (17 ) $ — $ (17 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 17 — 17 Total $ — $ — $ — KU Bonus Depreciation (b) $ (11 ) $ — $ (11 ) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 11 — 11 Total $ — $ — $ — (a) The above table reflects, for each item, the amount subject to change as a result of the TCJA and does not reflect the total amount of each item included in the return and the provision. (b) The TCJA increased the bonus depreciation percentage from 50% to 100% for qualified property acquired and placed in service after September 27, 2017 and before January 1, 2018. Increases in tax depreciation reduce the Registrants' taxes payable and increase net deferred tax liabilities with no impact to “Income Taxes” on the Statements of Income. (c) An increase in the consolidated federal net operating loss reduces net deferred tax liabilities with the opposite effect if there is a decrease in the consolidated federal net operating loss. These increases or decreases have no impact to “Income Taxes” on the Statements of Income. Income Tax Expense (Benefit) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 139 $ 161 $ (22 ) Foreign Tax Credits (157 ) (205 ) 48 Valuation of Foreign Tax Credit Carryforward 110 145 (35 ) Reduction in U.S. federal income tax rate 229 220 9 Total $ 321 $ 321 $ — PPL Electric Reduction in U.S. federal income tax rate $ (13 ) $ (13 ) $ — LKE Reduction in U.S. federal income tax rate $ 110 $ 112 $ (2 ) The Registrants' accounting related to the effects of the TCJA on financial results for the period ended December 31, 2017 is complete as of December 31, 2018 with respect to all provisional amounts. The Balance Sheets at December 31, 2017 reflect 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 The tax rate reduction impacts on non-regulated deferred tax assets and liabilities were recorded as an adjustment to the Registrants' deferred tax provisions, and have been reflected in "Income Taxes" on the Statement of Income for the year ended December 31, 2017 as follows: PPL PPL Electric LKE LG&E KU Income tax expense (benefit) $ 220 $ (13 ) $ 112 $ — $ — Under GAAP, the tax effect of changes in tax laws must be recognized in the period in which the law is enacted, or December 2017 for the TCJA. The changes enacted by the TCJA were recorded as an adjustment to the Registrants' deferred tax provisions, and have been reflected in "Income Taxes" on the Statement of Income for the year ended December 31, 2017 as follows: 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: 2018 2017 2016 Domestic income $ 1,127 $ 874 $ 1,463 Foreign income 1,158 1,038 1,087 Total $ 2,285 $ 1,912 $ 2,550
Components of Deferred Tax Assets and Liabilities	Significant components of PPL's deferred income tax assets and liabilities were as follows: 2018 2017 Deferred Tax Assets Deferred investment tax credits $ 31 $ 33 Regulatory liabilities 87 68 Income taxes due to customer 479 499 Accrued pension and postretirement costs 277 232 Federal loss carryforwards 325 356 State loss carryforwards 419 409 Federal and state tax credit carryforwards 392 455 Foreign capital loss carryforwards 313 329 Foreign loss carryforwards 1 2 Foreign - regulatory obligations — 2 Foreign - other 9 7 Contributions in aid of construction 139 134 Domestic - other 81 102 Unrealized losses on qualifying derivatives 7 10 Valuation allowances (808 ) (838 ) Total deferred tax assets 1,752 1,800 Deferred Tax Liabilities Domestic plant - net 3,359 3,168 Regulatory assets 314 288 Reacquired debt costs 12 15 Foreign plant - net 724 726 Foreign - pensions 83 32 Domestic - other 28 9 Total deferred tax liabilities 4,520 4,238 Net deferred tax liability $ 2,768 $ 2,438
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2018 , 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 $ 1,519 $ 319 $ — 2031-2037 Federal charitable contributions 29 6 — 2020-2022 State net operating losses 5,725 418 (370 ) 2019-2038 State charitable contributions 7 1 — 2020-2022 Foreign net operating losses 6 1 — Indefinite Foreign capital losses 1,842 313 (313 ) Indefinite Credit carryforwards Federal investment tax credit 133 — 2025-2036 Federal alternative minimum tax credit (a) 15 — Indefinite Federal foreign tax credits (b) 218 (113 ) 2024-2027 Federal - other 25 (8 ) 2019-2038 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 2018 $ 838 $ 26 $ — $ 56 (a) $ 808 2017 593 256 (b) — 11 838 2016 662 17 2 88 (c) 593 (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. (c) The reduction of the U.K. statutory income tax rate in 2016 resulted in a $19 million reduction in deferred tax assets and corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for additional information on the impact of the U.K. Finance Act 2016. In addition, deferred tax assets and corresponding valuation allowances were reduced in 2016 by approximately $65 million due to the effect of foreign currency exchange rates.
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ (19 ) $ 6 $ (14 ) Current - State 17 25 21 Current - Foreign 104 45 80 Total Current Expense 102 76 87 Deferred - Federal (a) 203 532 385 Deferred - State 100 88 89 Deferred - Foreign 107 133 86 Total Deferred Expense, excluding operating loss carryforwards 410 753 560 Amortization of investment tax credit (3 ) (3 ) (3 ) Tax expense (benefit) of operating loss carryforwards Deferred - Federal (20 ) (16 ) 25 Deferred - State (31 ) (26 ) (21 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards (51 ) (42 ) 4 Total income taxes $ 458 $ 784 $ 648 Total income tax expense - Federal $ 161 $ 519 $ 393 Total income tax expense - State 86 87 89 Total income tax expense - Foreign 211 178 166 Total income taxes $ 458 $ 784 $ 648 (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. 2018 2017 2016 Stock-based compensation recorded to Earnings reinvested $ — $ — $ (7 ) Other comprehensive income (6 ) (34 ) (6 ) Valuation allowance on state deferred taxes recorded to other comprehensive income — (1 ) 1 Total $ (6 ) $ (35 ) $ (12 )
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: 2018 2017 2016 Reconciliation of Income Tax Expense Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 480 $ 669 $ 893 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 40 46 46 Valuation allowance adjustments (b) 21 36 16 Impact of lower U.K. income tax rates(c) (25 ) (176 ) (177 ) U.S. income tax on foreign earnings - net of foreign tax credit (a)(d) 3 47 (42 ) Foreign income return adjustments — (8 ) 2 Impact of the U.K. Finance Act on deferred tax balances (e) (13 ) (16 ) (49 ) Depreciation and other items not normalized (11 ) (10 ) (10 ) Amortization of excess deferred federal and state income taxes(f) (37 ) — — Interest benefit on U.K. financing entities (17 ) (16 ) (17 ) Stock-based compensation 4 (3 ) (10 ) Deferred tax impact of U.S. tax reform (g) — 220 — Deferred tax impact of Kentucky tax reform (h) 9 — — Other (i) 4 (5 ) (4 ) Total increase (decrease) (22 ) 115 (245 ) Total income taxes $ 458 $ 784 $ 648 Effective income tax rate 20.0 % 41.0 % 25.4 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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. During 2018, 2017 and 2016, PPL recorded deferred income tax expense of $24 million , $16 million and $13 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 2018 compared with 2017. (d) During 2017, PPL recorded a federal income tax benefit of $35 million primarily attributable to U.K. pension contributions. During 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 . During 2016, PPL recorded lower income taxes primarily attributable to foreign tax credit carryforwards, arising from a decision to amend prior year tax returns to claim foreign tax credits rather than deduct foreign taxes. This decision was prompted by changes to the company's most recent business plan. (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 and recognized a $42 million deferred income tax benefit during 2016. (f) During 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. (g) During 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. (h) During 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. (i) During 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 abo
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: 2018 2017 2016 Taxes, other than income State gross receipts $ 103 $ 102 $ 100 State capital stock — (6 ) — Foreign property 134 127 135 Domestic Other 75 69 66 Total $ 312 $ 292 $ 301
Summary of Income Tax Examinations	With few exceptions, at December 31, 2018 , 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) 2013 and prior 2013 and prior 2013 and prior 2013 and prior 2013 and prior Pennsylvania (state) 2011 and prior 2011 and prior Kentucky (state) 2013 and prior 2013 and prior 2013 and prior 2013 and prior U.K. (foreign) 2015 and prior
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of PPL Electric's deferred income tax assets and liabilities were as follows: 2018 2017 Deferred Tax Assets Accrued pension and postretirement costs $ 110 $ 81 Contributions in aid of construction 118 117 Regulatory liabilities 35 25 Income taxes due to customers 181 193 State loss carryforwards 14 19 Federal loss carryforwards 79 91 Other 25 27 Total deferred tax assets 562 553 Deferred Tax Liabilities Electric utility plant - net 1,681 1,544 Reacquired debt costs 6 8 Regulatory assets 176 150 Other 19 5 Total deferred tax liabilities 1,882 1,707 Net deferred tax liability $ 1,320 $ 1,154
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2018 , PPL Electric had the following loss carryforwards and related deferred tax assets: Gross Deferred Tax Asset Expiration Loss carryforwards Federal net operating losses $ 370 $ 78 2031-2037 Federal charitable contributions 6 1 2020-2022 State net operating losses 180 14 2031-2032 State charitable contributions 5 — 2020-2022
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. 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ 2 $ (65 ) $ (29 ) Current - State 9 20 19 Total Current Expense (Benefit) 11 (45 ) (10 ) Deferred - Federal (a) 96 234 193 Deferred - State 37 29 29 Total Deferred Expense, excluding operating loss carryforwards 133 263 222 Tax expense (benefit) of operating loss carryforwards Deferred - Federal (8 ) (5 ) — Total Tax Expense (Benefit) of Operating Loss Carryforwards (8 ) (5 ) — Total income taxes $ 136 $ 213 $ 212 Total income tax expense - Federal $ 90 $ 164 $ 164 Total income tax expense - State 46 49 48 Total income taxes $ 136 $ 213 $ 212 (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. 2018 2017 2016 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 119 $ 201 $ 193 Increase (decrease) due to: State income taxes, net of federal income tax benefit (a) 43 36 36 Depreciation and other items not normalized (11 ) (8 ) (8 ) Amortization of excess deferred federal income taxes (a) (17 ) — — Stock-based compensation 1 (2 ) (6 ) Deferred tax impact of U.S. tax reform (b) — (13 ) — Other 1 (1 ) (3 ) Total increase (decrease) 17 12 19 Total income tax expense $ 136 $ 213 $ 212 Effective income tax rate 24.0 % 37.0 % 38.4 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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	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. 2018 2017 2016 Taxes, other than income State gross receipts $ 103 $ 102 $ 100 Property and other 6 5 5 Total $ 109 $ 107 $ 105
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: 2018 2017 Deferred Tax Assets Federal loss carryforwards $ 142 $ 150 State loss carryforwards 33 41 Federal tax credit carryforwards 169 181 Contributions in aid of construction 21 17 Regulatory liabilities 52 43 Accrued pension and postretirement costs 92 100 Income taxes due to customers 299 305 Deferred investment tax credits 32 33 Valuation allowances (8 ) (8 ) Other 29 33 Total deferred tax assets 861 895 Deferred Tax Liabilities Plant - net 1,671 1,615 Regulatory assets 138 138 Other 8 8 Total deferred tax liabilities 1,817 1,761 Net deferred tax liability $ 956 $ 866
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2018 , 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 $ 674 $ 142 $ — 2031 - 2037 Federal charitable contributions 11 2 — 2020 - 2022 State net operating losses 848 33 — 2029 - 2038 Credit carryforwards Federal investment tax credit 133 — 2025 - 2028, 2036 Federal alternative minimum tax credit (a) 14 — Indefinite Federal - other 22 (8 ) 2019-2038 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 2018 $ 8 $ — $ — $ 8 2017 11 4 (a) 7 (b) 8 2016 12 — 1 (b) 11 (a) Federal tax credits expiring in 2021 that are more likely than not to expire before being utilized. (b) Federal tax credit 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: 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ 31 $ 74 $ (36 ) Current - State 4 6 1 Total Current Expense (Benefit) 35 80 (35 ) Deferred - Federal (a) 65 268 248 Deferred - State 34 32 38 Total Deferred Expense, excluding benefits of operating loss carryforwards 99 300 286 Amortization of investment tax credit - Federal (3 ) (3 ) (3 ) Tax benefit of operating loss carryforwards Deferred - Federal (2 ) (2 ) 10 Deferred - State — — (1 ) Total Tax Expense (Benefit) of Operating Loss Carryforwards (2 ) (2 ) 9 Total income taxes (b) $ 129 $ 375 $ 257 Total income tax expense - Federal $ 91 $ 337 $ 219 Total income tax expense - State 38 38 38 Total income taxes (b) $ 129 $ 375 $ 257 (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) Excludes deferred federal and state tax expense (benefit) recorded to OCI of $5 million in 2018 , $(10) million in 2017 and $(16) million in 2016 .
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: 2018 2017 2016 Reconciliation of Income Tax Expense Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 121 $ 242 $ 240 Increase (decrease) due to: State income taxes, net of federal income tax benefit 22 26 26 Amortization of investment tax credit (3 ) (3 ) (3 ) Amortization of excess deferred federal and state income taxes (b) (20 ) (2 ) (1 ) Stock-based compensation 1 1 (3 ) Deferred tax impact of U.S. tax reform (c) — 112 — Deferred tax impact of state tax reform (d) 9 — — Other (e) (1 ) (1 ) (2 ) Total increase 8 133 17 Total income tax expense $ 129 $ 375 $ 257 Effective income tax rate 22.5 % 54.3 % 37.5 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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. (c) During 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) During 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) During 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 above.
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: 2018 2017 2016 Taxes, other than income Property and other $ 70 $ 65 $ 62 Total $ 70 $ 65 $ 62
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: 2018 2017 Deferred Tax Assets Federal loss carryforwards $ — $ 29 Contributions in aid of construction 14 11 Regulatory liabilities 24 21 Accrued pension and postretirement costs 16 14 Deferred investment tax credits 9 9 Income taxes due to customers 139 142 Other 15 19 Total deferred tax assets 217 245 Deferred Tax Liabilities Plant - net 751 724 Regulatory assets 88 88 Other 6 5 Total deferred tax liabilities 845 817 Net deferred tax liability $ 628 $ 572
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: 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ — $ — $ (22 ) Current - State 4 5 1 Total current Expense (Benefit) 4 5 (21 ) Deferred - Federal 51 112 134 Deferred - State 10 14 18 Total Deferred Expense, excluding benefits of operating loss carryforwards 61 126 152 Amortization of investment tax credit - Federal (1 ) (1 ) (1 ) Tax benefit of operating loss carryforwards Deferred - Federal — 1 (4 ) Total Tax Benefit of Operating Loss Carryforwards — 1 (4 ) Total income taxes $ 64 $ 131 $ 126 Total income tax expense - Federal $ 50 $ 112 $ 107 Total income tax expense - State 14 19 19 Total income taxes $ 64 $ 131 $ 126
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: 2018 2017 2016 Reconciliation of Income Tax Expense Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 62 $ 120 $ 115 Increase (decrease) due to: State income taxes, net of federal income tax benefit 11 14 12 Amortization of investment tax credit (1 ) (1 ) (1 ) Amortization of excess deferred federal and state income taxes (b) (8 ) (1 ) — Other — (1 ) — Total increase 2 11 11 Total income tax expense $ 64 $ 131 $ 126 Effective income tax rate 21.5 % 38.1 % 38.3 % (a) The U.S. federal corporate tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) During 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.
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: 2018 2017 2016 Taxes, other than income Property and other $ 36 $ 33 $ 32 Total $ 36 $ 33 $ 32
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: 2018 2017 Deferred Tax Assets Federal loss carryforwards $ — $ 13 Contributions in aid of construction 7 6 Regulatory liabilities 28 22 Accrued pension and postretirement costs 7 7 Deferred investment tax credits 23 24 Income taxes due to customers 160 163 Other 3 8 Total deferred tax assets 228 243 Deferred Tax Liabilities Plant - net 911 882 Regulatory assets 50 50 Other 2 2 Total deferred tax liabilities 963 934 Net deferred tax liability $ 735 $ 691
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: 2018 2017 2016 Income Tax Expense (Benefit) Current - Federal $ 22 $ — $ 31 Current - State 6 7 5 Total Current Expense (Benefit) 28 7 36 Deferred - Federal 40 138 131 Deferred - State 10 16 19 Total Deferred Expense, excluding benefits of operating loss carryforwards 50 154 150 Amortization of investment tax credit - Federal (2 ) (2 ) (2 ) Tax benefit of operating loss carryforwards Deferred - Federal — — (21 ) Total Tax Benefit of Operating Loss Carryforwards — — (21 ) Total income taxes $ 76 $ 159 $ 163 Total income tax expense - Federal $ 60 $ 136 $ 139 Total income tax expense - State 16 23 24 Total income taxes $ 76 $ 159 $ 163
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: 2018 2017 2016 Reconciliation of Income Tax Expense Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 76 $ 146 $ 150 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 15 16 Amortization of investment tax credit (2 ) (2 ) (2 ) Amortization of excess deferred federal and state income taxes (b) (12 ) (1 ) (1 ) Other 1 1 — Total increase (decrease) — 13 13 Total income tax expense $ 76 $ 159 $ 163 Effective income tax rate 21.0 % 38.0 % 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) During 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.
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: 2018 2017 2016 Taxes, other than income Property and other $ 34 $ 32 $ 30 Total $ 34 $ 32 $ 30

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2018 2017 Current Regulatory Assets: Environmental cost recovery $ — $ 5 $ — $ — Generation formula rate — 6 — — Gas supply clause 12 4 — — Smart meter rider 11 15 11 15 Plant outage costs 10 3 — — Other 3 1 — 1 Total current regulatory assets (a) $ 36 $ 34 $ 11 $ 16 Noncurrent Regulatory Assets: Defined benefit plans $ 963 $ 880 $ 558 $ 504 Taxes recoverable through future rates 3 3 3 3 Storm costs 56 33 22 — Unamortized loss on debt 45 54 22 29 Interest rate swaps 20 26 — — Terminated interest rate swaps 87 92 — — Accumulated cost of removal of utility plant 200 173 200 173 AROs 273 234 — — Act 129 compliance rider 19 — 19 — Other 7 9 — — Total noncurrent regulatory assets $ 1,673 $ 1,504 $ 824 $ 709 Current Regulatory Liabilities: Generation supply charge $ 33 $ 34 $ 33 $ 34 Transmission service charge 3 9 3 9 Environmental cost recovery 16 1 — — Universal service rider 27 26 27 26 Transmission formula rate 3 9 3 9 TCJA customer refund 20 — 3 — Storm damage expense rider 5 8 5 8 Other 15 8 — — Total current regulatory liabilities $ 122 $ 95 $ 74 $ 86 PPL PPL Electric 2018 2017 2018 2017 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 674 $ 677 $ — $ — Power purchase agreement - OVEC 59 68 — — Net deferred taxes 1,826 1,853 629 668 Defined benefit plans 37 27 5 — Terminated interest rate swaps 72 74 — — TCJA customer refund 41 — 41 — Other 5 5 — — Total noncurrent regulatory liabilities $ 2,714 $ 2,704 $ 675 $ 668 LKE LG&E KU 2018 2017 2018 2017 2018 2017 Current Regulatory Assets: Plant outage costs $ 10 $ 3 $ 7 $ 3 $ 3 $ — Generation formula rate — 6 — — — 6 Gas supply clause 12 4 12 4 — — Other 3 5 2 5 1 — Total current regulatory assets $ 25 $ 18 $ 21 $ 12 $ 4 $ 6 Noncurrent Regulatory Assets: Defined benefit plans $ 405 $ 376 $ 249 $ 234 $ 156 $ 142 Storm costs 34 33 20 18 14 15 Unamortized loss on debt 23 25 15 16 8 9 Interest rate swaps 20 26 20 26 — — Terminated interest rate swaps 87 92 51 54 36 38 AROs 273 234 75 61 198 173 Other 7 9 1 2 6 7 Total noncurrent regulatory assets $ 849 $ 795 $ 431 $ 411 $ 418 $ 384 Current Regulatory Liabilities: Environmental cost recovery $ 16 $ 1 $ 6 $ — $ 10 $ 1 Fuel adjustment clauses — 3 — — — 3 Gas line tracker 2 3 2 3 — — TCJA customer refund 17 — 7 — 10 — Generation formula Rate 7 — — — 7 — Other 6 2 2 — 4 2 Total current regulatory liabilities $ 48 $ 9 $ 17 $ 3 $ 31 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 674 $ 677 $ 279 $ 282 $ 395 $ 395 Power purchase agreement - OVEC 59 68 41 47 18 21 Net deferred taxes 1,197 1,185 557 552 640 633 Defined benefit plans 32 27 — — 32 27 Terminated interest rate swaps 72 74 36 37 36 37 Other 5 5 2 1 3 4 Total noncurrent regulatory liabilities $ 2,039 $ 2,036 $ 915 $ 919 $ 1,124 $ 1,117 (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, 2018
Debt Disclosure [Line Items]
Credit Facilities in Place at Period End	The following credit facilities were in place at: December 31, 2018 December 31, 2017 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) (c) Jan. 2023 £ 210 £ 157 £ — £ 54 £ 148 £ — WPD (South West) Syndicated Credit Facility (a) (c) July 2021 245 — — 245 — — WPD (East Midlands) Syndicated Credit Facility (a) (c) July 2021 300 38 — 262 180 — WPD (West Midlands) Syndicated Credit Facility (a) (c) July 2021 300 — — 300 120 — Uncommitted Credit Facilities 130 — 4 126 — 4 Total U.K. Credit Facilities (b) £ 1,185 £ 195 £ 4 £ 987 £ 448 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Jan. 2023 $ 950 $ — $ 669 $ 281 $ — $ 230 Bilateral Credit Facility (c) (d) Mar. 2019 100 — 15 85 — 18 Total PPL Capital Funding Credit Facilities $ 1,050 $ — $ 684 $ 366 $ — $ 248 PPL Electric Syndicated Credit Facility (c) (d) Jan. 2023 $ 650 $ — $ 1 $ 649 $ — $ 1 LG&E Syndicated Credit Facility (c) (d) Jan. 2023 $ 500 $ — $ 279 $ 221 $ — $ 199 Term Loan Credit Facility (c) (e) Oct. 2019 200 200 — — 100 — Total LG&E Credit Facilities $ 700 $ 200 $ 279 $ 221 $ 100 $ 199 KU Syndicated Credit Facility (c) (d) Jan. 2023 $ 400 $ — $ 235 $ 165 $ — $ 45 Letter of Credit Facility (c) (d) (f) Oct. 2020 198 — 198 — — 198 Total KU Credit Facilities $ 598 $ — $ 433 $ 165 $ — $ 243 (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, 2018 and 2017 included USD-denominated borrowings of $200 million for both periods, which bore interest at 3.17% and 2.17% . The unused capacity reflects the amount borrowed in GBP of £156 million as of the date borrowed. The WPD (East Midlands) amount borrowed at December 31, 2018 and December 31, 2017 was a GBP-denominated borrowing, which equated to $48 million and $244 million and bore interest at 1.12% . and 0.89% . The WPD (West Midlands) amount borrowed at December 31, 2017 was a GBP-denominated borrowing, which equated to $162 million and bore interest at 0.89% . At December 31, 2018 , the unused capacity under the U.K. credit facilities was approximately $1.3 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, LKE, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, as it relates to the syndicated and bilateral credit facilities and subject to certain conditions, PPL Capital Funding may request that the capacity of its facility expiring in March 2019 be increased by up to $30 million , LG&E and KU each may request up to a $100 million increase in its facility's capacity. (e) LG&E entered into a term loan credit agreement in October 2017 whereby it may borrow up to $200 million . The outstanding borrowings at December 31, 2018 and December 31, 2017 bore interest at an average rate of 2.97% and 2.06% . (f) KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted to loans rather than requiring immediate payment.
Commercial paper	The following commercial paper programs were in place at: December 31, 2018 December 31, 2017 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding 2.82% $ 1,000 $ 669 $ 331 1.64% $ 230 PPL Electric 650 — 650 — LG&E 2.94% 350 279 71 1.83% 199 KU 2.94% 350 235 115 1.97% 45 Total $ 2,350 $ 1,183 $ 1,167 $ 474
Long-term Debt	Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (g) 2018 2017 PPL U.S. Senior Unsecured Notes 3.88 % 2020 - 2047 $ 4,325 $ 4,575 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.99 % 2019 - 2048 7,705 7,314 Junior Subordinated Notes 5.68 % 2067 - 2073 930 930 Term Loan Credit Facility 2.97 % 2019 200 100 Total U.S. Long-term Debt 13,160 12,919 U.K. Senior Unsecured Notes (d) 5.13 % 2020 - 2040 6,471 6,351 Index-linked Senior Unsecured Notes (e) 1.45 % 2026 - 2056 1,063 1,012 Total U.K. Long-term Debt (f) 7,534 7,363 Total Long-term Debt Before Adjustments 20,694 20,282 Fair market value adjustments 16 21 Unamortized premium and (discount), net (e) 9 14 Unamortized debt issuance costs (120 ) (122 ) Total Long-term Debt 20,599 20,195 Less current portion of Long-term Debt 530 348 Total Long-term Debt, noncurrent $ 20,069 $ 19,847 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.22 % 2020 - 2048 $ 3,739 $ 3,339 Total Long-term Debt Before Adjustments 3,739 3,339 Unamortized discount (18 ) (16 ) Unamortized debt issuance costs (27 ) (25 ) Total Long-term Debt 3,694 3,298 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 3,694 $ 3,298 December 31, Weighted-Average Maturities (g) 2018 2017 LKE Senior Unsecured Notes 3.97 % 2020 - 2021 $ 725 $ 725 Term Loan Credit Facility 2.97 % 2019 200 100 First Mortgage Bonds (a) (c) 3.76 % 2019 - 2045 3,966 3,975 Long-term debt to affiliate 3.69 % 2026 - 2028 650 400 Total Long-term Debt Before Adjustments 5,541 5,200 Unamortized discount (13 ) (14 ) Unamortized debt issuance costs (26 ) (27 ) Total Long-term Debt 5,502 5,159 Less current portion of Long-term Debt 530 98 Total Long-term Debt, noncurrent $ 4,972 $ 5,061 LG&E Term Loan Credit Facility 2.97 % 2019 $ 200 $ 100 First Mortgage Bonds (a) (c) 3.58 % 2019 - 2045 1,624 1,624 Total Long-term Debt Before Adjustments 1,824 1,724 Unamortized discount (4 ) (4 ) Unamortized debt issuance costs (11 ) (11 ) Total Long-term Debt 1,809 1,709 Less current portion of Long-term Debt 434 98 Total Long-term Debt, noncurrent $ 1,375 $ 1,611 KU First Mortgage Bonds (a) (c) 3.89 % 2019 - 2045 $ 2,342 $ 2,351 Total Long-term Debt Before Adjustments 2,342 2,351 Unamortized discount (8 ) (9 ) Unamortized debt issuance costs (13 ) (14 ) Total Long-term Debt 2,321 2,328 Less current portion of Long-term Debt 96 — Total Long-term Debt, noncurrent $ 2,225 $ 2,328 (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 electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $9.4 billion and $8.5 billion at December 31, 2018 and 2017 . 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 $5.1 billion and $4.7 billion at December 31, 2018 and 2017 . 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 $6.3 billion and $6.0 billion at December 31, 2018 and 2017 . (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, 2018 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $505 million for LKE, comprised of $391 million and $114 million for LG&E and KU respectively. At December 31, 2018 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $375 million for LKE, comprised of $147 million and $228 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 ( $287 million at December 31, 2018 ) 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 2017 to 2018 was an increase of approximately £26 million ( $33 million ) resulting from inflation. In addition, this amount includes £319 million ( $407 million at December 31, 2018 ) 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 £5.3 billion ( $6.7 billion at December 31, 2018 ) 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, 2018 .
Long-term Debt Maturities	The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2019 through 2023 and thereafter are as follows: PPL PPL Electric LKE LG&E KU 2019 $ 530 $ — $ 530 $ 434 $ 96 2020 1,266 100 975 — 500 2021 1,248 400 348 98 — 2022 1,274 474 — — — 2023 2,233 90 13 — 13 Thereafter 14,143 2,675 3,675 1,292 1,733 Total $ 20,694 $ 3,739 $ 5,541 $ 1,824 $ 2,342

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2018
Leases [Line Items]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are 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]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are 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]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are 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]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2018 2017 2016 PPL $ 45 $ 45 $ 50 LKE 29 26 26 LG&E 16 15 15 KU 12 11 11
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are 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, 2018
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: 2018 2017 2016 PPL $ 30.58 $ 35.30 $ 33.84 PPL Electric 30.00 35.45 34.32 LKE 30.98 35.25 33.73
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2018 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,291,649 $ 34.07 Granted 369,308 30.58 Vested (529,263 ) 32.97 Forfeited (33,491 ) 33.30 Nonvested, end of period (a) 1,098,203 33.45 PPL Electric Nonvested, beginning of period 184,416 $ 34.20 Transfer between registrants (2,906 ) 33.95 Granted 76,051 30.00 Vested (56,352 ) 32.39 Forfeited (13,872 ) 33.50 Nonvested, end of period 187,337 33.09 LKE Nonvested, beginning of period 231,557 $ 34.01 Transfer between registrants (1,284 ) 33.98 Granted 58,377 30.98 Vested (154,606 ) 33.38 Forfeited (1,014 ) 29.52 Nonvested, end of period 133,030 33.45 (a) Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.
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: 2018 2017 2016 PPL $ 16 $ 20 $ 30 PPL Electric 2 3 3 LKE 5 4 5
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2018 2017 2016 Expected stock volatility 17.60 % 17.40 % 19.60 % Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 The weighted-average grant date fair value of ROE performance units granted was: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29
Performance Units, Activity Rollforward	TSR performance unit activity for 2018 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 978,231 $ 36.67 Granted 263,593 38.26 TSR Performance Units Weighted- Average Grant Date Fair Value Per Share Vested (89,015 ) 34.78 Forfeited (a) (312,685 ) 35.26 Nonvested, end of period 840,124 37.89 PPL Electric Nonvested, beginning of period 75,513 $ 37.00 Granted 22,394 38.37 Vested (5,817 ) 35.34 Forfeited (a) (24,227 ) 36.27 Nonvested, end of period 67,863 37.86 LKE Nonvested, beginning of period 180,289 $ 36.69 Granted 53,961 38.32 Vested (14,547 ) 35.04 Forfeited (a) (70,707 ) 35.91 Nonvested, end of period 148,996 37.81 (a) Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2018 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 96,928 $ 34.42 Granted 234,664 32.21 Forfeited (2,634 ) 32.96 Nonvested, end of period 328,958 32.86 PPL Electric Nonvested, beginning of period 8,696 $ 34.41 Granted 19,899 32.32 Forfeited (2,635 ) 32.96 Nonvested, end of period 25,960 32.96 LKE Nonvested, beginning of period 20,539 $ 34.29 Granted 49,081 32.28 Nonvested, end of period 69,620 32.87 The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 The weighted-average grant date fair value of ROE performance units granted was: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29
Stock Options, Activity Rollforward	Stock option activity for 2018 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 3,762,183 $ 29.42 Exercised (151,750 ) 28.43 Forfeited (695,908 ) 42.87 Outstanding and exercisable at end of period 2,914,525 26.26 3.4 $ 6
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric and LKE includes an allocation of PPL Services' expense, was: 2018 2017 2016 PPL $ 25 $ 32 $ 27 PPL Electric 10 18 16 LKE 8 8 7 The income tax benefit related to above compensation expense was as follows: 2018 2017 2016 PPL $ 10 $ 13 $ 12 PPL Electric 3 8 7 LKE 2 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2018 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 10 1.6 PPL Electric 2 1.7 LKE 1 1.4
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: 2018 2017 2016 PPL $ 30.58 $ 35.30 $ 33.84 PPL Electric 30.00 35.45 34.32 LKE 30.98 35.25 33.73
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2018 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,291,649 $ 34.07 Granted 369,308 30.58 Vested (529,263 ) 32.97 Forfeited (33,491 ) 33.30 Nonvested, end of period (a) 1,098,203 33.45 PPL Electric Nonvested, beginning of period 184,416 $ 34.20 Transfer between registrants (2,906 ) 33.95 Granted 76,051 30.00 Vested (56,352 ) 32.39 Forfeited (13,872 ) 33.50 Nonvested, end of period 187,337 33.09 LKE Nonvested, beginning of period 231,557 $ 34.01 Transfer between registrants (1,284 ) 33.98 Granted 58,377 30.98 Vested (154,606 ) 33.38 Forfeited (1,014 ) 29.52 Nonvested, end of period 133,030 33.45 (a) Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.
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: 2018 2017 2016 PPL $ 16 $ 20 $ 30 PPL Electric 2 3 3 LKE 5 4 5
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2018 2017 2016 Expected stock volatility 17.60 % 17.40 % 19.60 % Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 The weighted-average grant date fair value of ROE performance units granted was: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29
Performance Units, Activity Rollforward	TSR performance unit activity for 2018 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 978,231 $ 36.67 Granted 263,593 38.26 TSR Performance Units Weighted- Average Grant Date Fair Value Per Share Vested (89,015 ) 34.78 Forfeited (a) (312,685 ) 35.26 Nonvested, end of period 840,124 37.89 PPL Electric Nonvested, beginning of period 75,513 $ 37.00 Granted 22,394 38.37 Vested (5,817 ) 35.34 Forfeited (a) (24,227 ) 36.27 Nonvested, end of period 67,863 37.86 LKE Nonvested, beginning of period 180,289 $ 36.69 Granted 53,961 38.32 Vested (14,547 ) 35.04 Forfeited (a) (70,707 ) 35.91 Nonvested, end of period 148,996 37.81 (a) Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2018 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 96,928 $ 34.42 Granted 234,664 32.21 Forfeited (2,634 ) 32.96 Nonvested, end of period 328,958 32.86 PPL Electric Nonvested, beginning of period 8,696 $ 34.41 Granted 19,899 32.32 Forfeited (2,635 ) 32.96 Nonvested, end of period 25,960 32.96 LKE Nonvested, beginning of period 20,539 $ 34.29 Granted 49,081 32.28 Nonvested, end of period 69,620 32.87
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric and LKE includes an allocation of PPL Services' expense, was: 2018 2017 2016 PPL $ 25 $ 32 $ 27 PPL Electric 10 18 16 LKE 8 8 7 The income tax benefit related to above compensation expense was as follows: 2018 2017 2016 PPL $ 10 $ 13 $ 12 PPL Electric 3 8 7 LKE 2 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2018 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 10 1.6 PPL Electric 2 1.7 LKE 1 1.4
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: 2018 2017 2016 PPL $ 30.58 $ 35.30 $ 33.84 PPL Electric 30.00 35.45 34.32 LKE 30.98 35.25 33.73
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2018 was: Restricted Shares/Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 1,291,649 $ 34.07 Granted 369,308 30.58 Vested (529,263 ) 32.97 Forfeited (33,491 ) 33.30 Nonvested, end of period (a) 1,098,203 33.45 PPL Electric Nonvested, beginning of period 184,416 $ 34.20 Transfer between registrants (2,906 ) 33.95 Granted 76,051 30.00 Vested (56,352 ) 32.39 Forfeited (13,872 ) 33.50 Nonvested, end of period 187,337 33.09 LKE Nonvested, beginning of period 231,557 $ 34.01 Transfer between registrants (1,284 ) 33.98 Granted 58,377 30.98 Vested (154,606 ) 33.38 Forfeited (1,014 ) 29.52 Nonvested, end of period 133,030 33.45 (a) Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.
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: 2018 2017 2016 PPL $ 16 $ 20 $ 30 PPL Electric 2 3 3 LKE 5 4 5
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2018 2017 2016 Expected stock volatility 17.60 % 17.40 % 19.60 % Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2018 2017 2016 PPL $ 38.26 $ 38.38 $ 35.74 PPL Electric 38.37 38.37 35.68 LKE 38.32 38.24 35.28 The weighted-average grant date fair value of ROE performance units granted was: 2018 2017 PPL $ 32.21 $ 32.42 PPL Electric 32.32 34.41 LKE 32.28 34.29
Performance Units, Activity Rollforward	TSR performance unit activity for 2018 was: TSR Performance Units Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 978,231 $ 36.67 Granted 263,593 38.26 TSR Performance Units Weighted- Average Grant Date Fair Value Per Share Vested (89,015 ) 34.78 Forfeited (a) (312,685 ) 35.26 Nonvested, end of period 840,124 37.89 PPL Electric Nonvested, beginning of period 75,513 $ 37.00 Granted 22,394 38.37 Vested (5,817 ) 35.34 Forfeited (a) (24,227 ) 36.27 Nonvested, end of period 67,863 37.86 LKE Nonvested, beginning of period 180,289 $ 36.69 Granted 53,961 38.32 Vested (14,547 ) 35.04 Forfeited (a) (70,707 ) 35.91 Nonvested, end of period 148,996 37.81 (a) Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2018 was: ROE Performance Unit Weighted- Average Grant Date Fair Value Per Share PPL Nonvested, beginning of period 96,928 $ 34.42 Granted 234,664 32.21 Forfeited (2,634 ) 32.96 Nonvested, end of period 328,958 32.86 PPL Electric Nonvested, beginning of period 8,696 $ 34.41 Granted 19,899 32.32 Forfeited (2,635 ) 32.96 Nonvested, end of period 25,960 32.96 LKE Nonvested, beginning of period 20,539 $ 34.29 Granted 49,081 32.28 Nonvested, end of period 69,620 32.87
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric and LKE includes an allocation of PPL Services' expense, was: 2018 2017 2016 PPL $ 25 $ 32 $ 27 PPL Electric 10 18 16 LKE 8 8 7 The income tax benefit related to above compensation expense was as follows: 2018 2017 2016 PPL $ 10 $ 13 $ 12 PPL Electric 3 8 7 LKE 2 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2018 , unrecognized compensation expense related to nonvested stock awards was: Unrecognized Compensation Expense Weighted- Average Period for Recognition PPL $ 10 1.6 PPL Electric 2 1.7 LKE 1 1.4

Retirement and Postemployment_2

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 2018 2017 2016 2018 2017 2016 Net periodic defined benefit costs (credits): Service cost $ 62 $ 65 $ 66 $ 82 $ 76 $ 69 $ 7 $ 7 $ 7 Interest cost 156 168 174 185 178 235 21 23 26 Expected return on plan assets (249 ) (231 ) (228 ) (587 ) (514 ) (504 ) (23 ) (22 ) (22 ) Amortization of: Prior service cost (credit) 10 10 8 — — — (1 ) (1 ) — Actuarial (gain) loss 84 69 50 151 144 138 — 1 1 Net periodic defined benefit costs (credits) prior to settlements and termination benefits 63 81 70 (169 ) (116 ) (62 ) 4 8 12 Settlements — 1 3 — — — — — — Termination benefits — 1 — — — — — — — Net periodic defined benefit costs (credits) $ 63 $ 83 $ 73 $ (169 ) $ (116 ) $ (62 ) $ 4 $ 8 $ 12 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement — (1 ) (3 ) — — — — — — Net (gain) loss 157 27 253 201 346 7 8 (28 ) 9 Prior service cost (credit) 1 (1 ) 15 13 — — — 8 — Amortization of: Prior service (cost) credit (10 ) (10 ) (8 ) — — — 1 1 (1 ) Actuarial gain (loss) (84 ) (69 ) (50 ) (151 ) (144 ) (138 ) — (1 ) (1 ) Total recognized in OCI and regulatory assets/liabilities (a) 64 (54 ) 207 63 202 (131 ) 9 (20 ) 7 Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (a) $ 127 $ 29 $ 280 $ (106 ) $ 86 $ (193 ) $ 13 $ (12 ) $ 19 (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 2018 2017 2016 2018 2017 2016 OCI $ 90 $ (53 ) $ 236 $ 20 $ (25 ) $ 7 Regulatory assets/liabilities (26 ) (1 ) (29 ) (11 ) 5 — Total recognized in OCI and regulatory assets/liabilities $ 64 $ (54 ) $ 207 $ 9 $ (20 ) $ 7
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 2018 2017 2016 2018 2017 2016 2018 2017 2016 PPL $ 40 $ 59 $ 53 $ (226 ) $ (151 ) $ (95 ) $ 2 $ 5 $ 7 PPL Electric (a) 4 12 10 (1 ) — 1 LKE (b) 21 28 24 3 5 6 LG&E (b) 4 8 8 2 3 3 KU (a) (b) 2 4 5 1 1 2 (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, $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2018 , $4 million for LG&E and $2 million for KU were recorded as regulatory assets in 2017 and $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2016 .
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 2018 2017 2018 2017 2018 2017 PPL Discount rate 4.35 % 3.70 % 2.98 % 2.65 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.78 % 3.50 % 3.50 % 3.76 % 3.75 % LKE Discount rate 4.35 % 3.69 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 4.33 % 3.65 % 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 2018 2017 2016 2018 2017 2016 2018 2017 2016 PPL Discount rate service cost 3.70 % 4.21 % 4.59 % 2.73 % 2.99 % 3.90 % 3.64 % 4.11 % 4.48 % Discount rate interest cost 3.70 % 4.21 % 4.59 % 2.31 % 2.41 % 3.14 % 3.64 % 4.11 % 4.48 % Rate of compensation increase 3.78 % 3.95 % 3.93 % 3.50 % 3.50 % 4.00 % 3.75 % 3.92 % 3.91 % Expected return on plan assets 7.25 % 7.00 % 7.00 % 7.23 % 7.22 % 7.20 % 6.40 % 6.21 % 6.11 % LKE Discount rate 3.69 % 4.19 % 4.56 % 3.65 % 4.12 % 4.49 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.00 % 7.00 % 7.15 % 6.82 % 6.82 % LG&E Discount rate 3.65 % 4.13 % 4.49 % Expected return on plan assets (a) 7.25 % 7.00 % 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: 2018 2017 2016 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.6 % 6.6 % 7.0 % – cost 6.6 % 7.0 % 6.8 % 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 2023 2022 2022 – cost 2022 2022 2020
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 2018 2017 2018 2017 2018 2017 Change in Benefit Obligation Benefit Obligation, beginning of period $ 4,288 $ 4,079 $ 8,219 $ 7,383 $ 589 $ 591 Service cost 62 65 82 76 7 7 Interest cost 156 168 185 178 21 23 Participant contributions — — 13 13 13 14 Plan amendments 1 (1 ) 12 — — 8 Actuarial (gain) loss (352 ) 233 (406 ) 293 (34 ) 4 Settlements — (6 ) — (1 ) — — Termination benefits — 1 — — — — Gross benefits paid (272 ) (251 ) (381 ) (345 ) (58 ) (59 ) Federal subsidy — — — — — 1 Currency conversion — — (449 ) 622 — — Benefit Obligation, end of period 3,883 4,288 7,275 8,219 538 589 Change in Plan Assets Plan assets at fair value, beginning of period 3,488 3,243 8,490 7,211 405 378 Actual return on plan assets (260 ) 437 (30 ) 480 (20 ) 54 Employer contributions 153 65 188 486 23 15 Participant contributions — — 13 13 11 13 Transfer out (a) — — — — (65 ) — Settlements — (6 ) — (1 ) — — Gross benefits paid (272 ) (251 ) (381 ) (345 ) (53 ) (55 ) Currency conversion — — (479 ) 646 — — Plan assets at fair value, end of period 3,109 3,488 7,801 8,490 301 405 Funded Status, end of period $ (774 ) $ (800 ) $ 526 $ 271 $ (237 ) $ (184 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ — $ — $ 535 $ 284 $ 2 $ 2 Current liability (13 ) (13 ) (1 ) — (3 ) (3 ) Noncurrent liability (761 ) (787 ) (8 ) (13 ) (236 ) (183 ) Net amount recognized, end of period $ (774 ) $ (800 ) $ 526 $ 271 $ (237 ) $ (184 ) Pension Benefits U.S. U.K. Other Postretirement Benefits 2018 2017 2018 2017 2018 2017 Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 40 $ 49 $ 12 $ — $ 10 $ 9 Net actuarial (gain) loss 1,207 1,134 2,806 2,755 24 16 Total (b) $ 1,247 $ 1,183 $ 2,818 $ 2,755 $ 34 $ 25 Total accumulated benefit obligation for defined benefit pension plans $ 3,668 $ 4,000 $ 6,689 $ 7,542 (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 2018 2017 2018 2017 AOCI $ 370 $ 374 $ 21 $ 15 Regulatory assets/liabilities 877 809 13 10 Total $ 1,247 $ 1,183 $ 34 $ 25
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 2018 2017 2018 2017 Projected benefit obligation $ 3,883 $ 4,288 $ 9 $ 3,083 Fair value of plan assets 3,109 3,488 — 3,070 U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2018 2017 2018 2017 Accumulated benefit obligation $ 3,668 $ 4,000 $ 9 $ 10 Fair value of plan assets 3,109 3,488 — —
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 2018 2018 (a) 2017 (a) Target Asset Allocation (a) Growth Portfolio 55 % 56 % 55 % Equity securities 30 % 32 % Debt securities (b) 15 % 14 % Alternative investments 10 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (b) 39 % 39 % Derivatives 4 % 4 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2018 December 31, 2017 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 $ 220 $ 220 $ — $ — $ 301 $ 301 $ — $ — Equity securities: U.S. Equity 159 159 — — 229 229 — — U.S. Equity fund measured at NAV (a) 340 — — — 364 — — — International equity fund at NAV (a) 466 — — — 538 — — — Commingled debt measured at NAV (a) 543 — — — 611 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 212 212 — — 186 186 — — Corporate 899 — 874 25 883 — 870 13 Other 17 — 17 — 10 — 10 — Alternative investments: Real estate measured at NAV (a) 90 — — — 109 — — — Private equity measured at NAV (a) 65 — — — 80 — — — Hedge funds measured at NAV (a) 175 — — — 175 — — — December 31, 2018 December 31, 2017 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 33 — 33 — 51 — 51 — Insurance contracts 21 — — 21 24 — — 24 PPL Services Corporation Master Trust assets, at fair value 3,240 $ 591 $ 924 $ 46 3,561 $ 716 $ 931 $ 37 Receivables and payables, net (b) (2 ) 72 401(h) accounts restricted for other postretirement benefit obligations (129 ) (145 ) Total PPL Services Corporation Master Trust pension assets $ 3,109 $ 3,488 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2017 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 27 $ 40 Actual return on plan assets Relating to assets still held at the reporting date — 1 1 Purchases, sales and settlements — (4 ) (4 ) Balance at end of period $ 13 $ 24 $ 37
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 2018 2017 2018 Asset Class U.S. Equity securities 40 % 47 % 45 % Debt securities (a) 56 % 49 % 50 % Cash and cash equivalents (b) 4 % 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, 2018 December 31, 2017 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 $ — $ — $ 10 $ 10 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 69 — — — 123 — — — Commingled debt fund measured at NAV (a) 68 — — — 96 — — — Debt securities: Corporate bonds 28 — 28 — 30 — 30 — Total VEBA trust assets, at fair value 171 $ 6 $ 28 $ — 259 $ 10 $ 30 $ — Receivables and payables, net (b) 1 1 401(h) account assets 129 145 Total other postretirement benefit plan assets $ 301 $ 405 (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 2018 2017 2018 Asset Class Cash and cash equivalents 2 % 2 % — % Equity securities U.K. — % 2 % 2 % European (excluding the U.K.) 1 % 1 % 1 % Asian-Pacific 1 % 1 % 1 % North American 1 % 1 % 1 % Emerging markets 1 % 1 % 1 % Global equities 19 % 16 % 10 % Global Tactical Asset Allocation 31 % 33 % 41 % Debt securities (a) 38 % 37 % 38 % Alternative investments 6 % 6 % 5 % 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, 2018 December 31, 2017 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 $ 147 $ 147 $ — $ — $ 216 $ 216 $ — $ — Equity securities measured at NAV (a) : U.K. companies 27 — — — 157 — — — European companies (excluding the U.K.) 76 — — — 98 — — — Asian-Pacific companies 49 — — — 60 — — — North American companies 105 — — — 123 — — — Emerging markets companies 44 — — — 62 — — — Global Equities 1,465 — — — 1,335 — — — Other 2,437 — — — 2,807 — — — Debt Securities: U.K. corporate bonds 4 — 4 — 3 — 3 — U.K. gilts 2,933 — 2,933 — 3,137 — 3,137 — Alternative investments: Real estate measured at NAV (a) 485 — — — 492 — — — Fair value - U.K. pension plans 7,772 $ 147 $ 2,937 $ — 8,490 $ 216 $ 3,140 $ — Receivables and payables, net (b) 29 — Total U.K. pension assets $ 7,801 $ 8,490 (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 2019 $ 274 $ 50 $ — 2020 266 50 1 2021 265 49 — 2022 265 48 1 2023 264 46 — 2024-2028 1,290 210 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 2019 $ 337 2020 340 2021 344 2022 349 2023 352 2024-2028 1,781
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: 2018 2017 2016 PPL $ 40 $ 36 $ 35 PPL Electric 6 6 6 LKE 20 18 17 LG&E 6 5 5 KU 5 4 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: 2018 2017 Pension $ 285 $ 246 Other postretirement benefits 120 62
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 2018 2017 2016 2018 2017 2016 Net periodic defined benefit costs (credits): Service cost $ 25 $ 24 $ 23 $ 4 $ 4 $ 5 Interest cost 63 68 71 8 9 9 Expected return on plan assets (102 ) (92 ) (91 ) (9 ) (7 ) (6 ) Amortization of: Prior service cost 9 8 8 1 1 3 Actuarial (gain) loss (a) 35 31 21 — — (1 ) Net periodic defined benefit costs (b) $ 30 $ 39 $ 32 $ 4 $ 7 $ 10 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (gain) loss $ 40 $ 30 $ 119 $ 1 $ (14 ) $ 6 Prior service cost — 7 — — 8 — Amortization of: Prior service credit (9 ) (8 ) (8 ) (1 ) (1 ) (3 ) Actuarial gain (loss) (35 ) (32 ) (21 ) — — 1 Total recognized in OCI and regulatory assets/liabilities (4 ) (3 ) 90 — (7 ) 4 Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 26 $ 36 $ 122 $ 4 $ — $ 14 (a) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LKE's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $11 million in 2018 and 2017 and $6 million in 2016 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $6 million in 2018 and $5 million in 2017 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice.
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 2018 2017 2016 2018 2017 2016 OCI $ (25 ) $ 33 $ 42 $ 4 $ (2 ) $ 2 Regulatory assets/liabilities 21 (36 ) 48 (4 ) (5 ) 2 Total recognized in OCI and regulatory assets/liabilities $ (4 ) $ (3 ) $ 90 $ — $ (7 ) $ 4
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 2018 2017 2018 2017 2018 2017 PPL Discount rate 4.35 % 3.70 % 2.98 % 2.65 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.78 % 3.50 % 3.50 % 3.76 % 3.75 % LKE Discount rate 4.35 % 3.69 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 4.33 % 3.65 % 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 2018 2017 2016 2018 2017 2016 2018 2017 2016 PPL Discount rate service cost 3.70 % 4.21 % 4.59 % 2.73 % 2.99 % 3.90 % 3.64 % 4.11 % 4.48 % Discount rate interest cost 3.70 % 4.21 % 4.59 % 2.31 % 2.41 % 3.14 % 3.64 % 4.11 % 4.48 % Rate of compensation increase 3.78 % 3.95 % 3.93 % 3.50 % 3.50 % 4.00 % 3.75 % 3.92 % 3.91 % Expected return on plan assets 7.25 % 7.00 % 7.00 % 7.23 % 7.22 % 7.20 % 6.40 % 6.21 % 6.11 % LKE Discount rate 3.69 % 4.19 % 4.56 % 3.65 % 4.12 % 4.49 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.00 % 7.00 % 7.15 % 6.82 % 6.82 % LG&E Discount rate 3.65 % 4.13 % 4.49 % Expected return on plan assets (a) 7.25 % 7.00 % 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: 2018 2017 2016 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.6 % 6.6 % 7.0 % – cost 6.6 % 7.0 % 6.8 % 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 2023 2022 2022 – cost 2022 2022 2020
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 2018 2017 2018 2017 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,771 $ 1,669 $ 223 $ 220 Service cost 25 24 4 4 Interest cost 63 68 8 9 Participant contributions — — 8 8 Plan amendments (a) — 6 — 8 Actuarial (gain) loss (b) (168 ) 113 (16 ) (7 ) Gross benefits paid (a) (111 ) (109 ) (22 ) (19 ) Benefit Obligation, end of period 1,580 1,771 205 223 Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 Change in Plan Assets Plan assets at fair value, beginning of period 1,402 1,315 116 98 Actual return on plan assets (106 ) 175 (9 ) 14 Employer contributions 109 21 24 15 Participant contributions — — 8 8 Gross benefits paid (111 ) (109 ) (22 ) (19 ) Plan assets at fair value, end of period 1,294 1,402 117 116 Funded Status, end of period $ (286 ) $ (369 ) $ (88 ) $ (107 ) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ — $ — $ 2 $ 2 Current liability (4 ) (4 ) (3 ) (3 ) Noncurrent liability (282 ) (365 ) (87 ) (106 ) Net amount recognized, end of period $ (286 ) $ (369 ) $ (88 ) $ (107 ) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost $ 35 $ 44 $ 12 $ 13 Net actuarial (gain) loss 439 434 (25 ) (26 ) Total $ 474 $ 478 $ (13 ) $ (13 ) Total accumulated benefit obligation for defined benefit pension plans $ 1,467 $ 1,616 (a) The pension plans were amended in December 2015 to allow active participants and terminated vested participants who had not previously elected a form of payment of their benefit to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. Gross benefits paid by the plans include lump-sum cash payments made to participants during 2018 and 2017 of $52 million and $50 million in connection with these offerings. (b) The actuarial (gain) loss for all pension plans in 2018 and 2017 was primarily related to change 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 2018 2017 2018 2017 AOCI $ 118 $ 144 $ 10 $ 6 Regulatory assets/liabilities 356 334 (23 ) (19 ) Total $ 474 $ 478 $ (13 ) $ (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 2018 2017 Projected benefit obligation $ 1,580 $ 1,771 Fair value of plan assets 1,294 1,402 ABO in excess of plan assets 2018 2017 Accumulated benefit obligation $ 1,467 $ 1,616 Fair value of plan assets 1,294 1,402
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 2018 2018 (a) 2017 (a) Target Asset Allocation (a) Growth Portfolio 55 % 56 % 55 % Equity securities 30 % 32 % Debt securities (b) 15 % 14 % Alternative investments 10 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (b) 39 % 39 % Derivatives 4 % 4 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2018 December 31, 2017 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 $ 220 $ 220 $ — $ — $ 301 $ 301 $ — $ — Equity securities: U.S. Equity 159 159 — — 229 229 — — U.S. Equity fund measured at NAV (a) 340 — — — 364 — — — International equity fund at NAV (a) 466 — — — 538 — — — Commingled debt measured at NAV (a) 543 — — — 611 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 212 212 — — 186 186 — — Corporate 899 — 874 25 883 — 870 13 Other 17 — 17 — 10 — 10 — Alternative investments: Real estate measured at NAV (a) 90 — — — 109 — — — Private equity measured at NAV (a) 65 — — — 80 — — — Hedge funds measured at NAV (a) 175 — — — 175 — — — December 31, 2018 December 31, 2017 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 33 — 33 — 51 — 51 — Insurance contracts 21 — — 21 24 — — 24 PPL Services Corporation Master Trust assets, at fair value 3,240 $ 591 $ 924 $ 46 3,561 $ 716 $ 931 $ 37 Receivables and payables, net (b) (2 ) 72 401(h) accounts restricted for other postretirement benefit obligations (129 ) (145 ) Total PPL Services Corporation Master Trust pension assets $ 3,109 $ 3,488 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2017 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 27 $ 40 Actual return on plan assets Relating to assets still held at the reporting date — 1 1 Purchases, sales and settlements — (4 ) (4 ) Balance at end of period $ 13 $ 24 $ 37
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, 2018 December 31, 2017 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 $ — $ — $ 10 $ 10 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 69 — — — 123 — — — Commingled debt fund measured at NAV (a) 68 — — — 96 — — — Debt securities: Corporate bonds 28 — 28 — 30 — 30 — Total VEBA trust assets, at fair value 171 $ 6 $ 28 $ — 259 $ 10 $ 30 $ — Receivables and payables, net (b) 1 1 401(h) account assets 129 145 Total other postretirement benefit plan assets $ 301 $ 405 (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 2019 $ 112 $ 15 $ — 2020 112 15 — 2021 113 16 — 2022 113 16 1 2023 112 16 — 2024-2028 547 78 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 2018 2017 2016 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 $ 1 Interest cost 12 13 15 Expected return on plan assets (22 ) (22 ) (21 ) Amortization of: Prior service cost 5 5 4 Actuarial loss (a) 7 9 7 Net periodic defined benefit costs (b) $ 3 $ 6 $ 6 Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: Net (gain) loss $ 22 $ (9 ) $ 22 Prior service cost — 7 — Amortization of: Prior service credit (5 ) (5 ) (4 ) Actuarial gain (7 ) (9 ) (7 ) Total recognized in regulatory assets/liabilities 10 (16 ) 11 Total recognized in net periodic defined benefit costs and regulatory assets $ 13 $ (10 ) $ 17 (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 $2 million in 2018 , $7 million in 2017 and $5 million in 2016 . (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $6 million in 2018 and $5 million in 2017 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice.
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 2018 2017 2016 2018 2017 2016 LG&E Non-Union Only $ 2 $ 5 $ 4 $ 2 $ 3 $ 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 2018 2017 2018 2017 2018 2017 PPL Discount rate 4.35 % 3.70 % 2.98 % 2.65 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.78 % 3.50 % 3.50 % 3.76 % 3.75 % LKE Discount rate 4.35 % 3.69 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate 4.33 % 3.65 % 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 2018 2017 2016 2018 2017 2016 2018 2017 2016 PPL Discount rate service cost 3.70 % 4.21 % 4.59 % 2.73 % 2.99 % 3.90 % 3.64 % 4.11 % 4.48 % Discount rate interest cost 3.70 % 4.21 % 4.59 % 2.31 % 2.41 % 3.14 % 3.64 % 4.11 % 4.48 % Rate of compensation increase 3.78 % 3.95 % 3.93 % 3.50 % 3.50 % 4.00 % 3.75 % 3.92 % 3.91 % Expected return on plan assets 7.25 % 7.00 % 7.00 % 7.23 % 7.22 % 7.20 % 6.40 % 6.21 % 6.11 % LKE Discount rate 3.69 % 4.19 % 4.56 % 3.65 % 4.12 % 4.49 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.00 % 7.00 % 7.15 % 6.82 % 6.82 % LG&E Discount rate 3.65 % 4.13 % 4.49 % Expected return on plan assets (a) 7.25 % 7.00 % 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	Allocations to LG&E resulted in liabilities at December 31 as follows: 2018 2017 Pension $ 7 $ 44 Other postretirement benefits 65 74 (LG&E) The funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2018 2017 Change in Benefit Obligation Benefit Obligation, beginning of period $ 326 $ 329 Service cost 1 1 Interest cost 12 13 Plan amendments (a) — 6 Actuarial (gain) loss (24 ) 11 Gross benefits paid (a) (30 ) (34 ) Benefit Obligation, end of period 285 326 Change in Plan Assets Plan assets at fair value, beginning of period 325 318 Actual return on plan assets (24 ) 41 Employer contributions 10 — Gross benefits paid (30 ) (34 ) Plan assets at fair value, end of period 281 325 Funded Status, end of period $ (4 ) $ (1 ) Amounts recognized in the Balance Sheets consist of: Noncurrent liability $ (4 ) $ (1 ) Net amount recognized, end of period $ (4 ) $ (1 ) Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost $ 22 $ 27 Net actuarial loss 107 92 Total $ 129 $ 119 Total accumulated benefit obligation for defined benefit pension plan $ 285 $ 326 (a) The pension plan was amended in December 2015 to allow active participants and terminated vested participants who had not previously elected a form of payment of their benefit to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. Gross benefits paid by the plan include lump-sum cash payments made to participants during 2018 and 2017 of $16 million and $19 million in connection with this offering.
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 2018 2018 (a) 2017 (a) Target Asset Allocation (a) Growth Portfolio 55 % 56 % 55 % Equity securities 30 % 32 % Debt securities (b) 15 % 14 % Alternative investments 10 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (b) 39 % 39 % Derivatives 4 % 4 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2018 December 31, 2017 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 $ 220 $ 220 $ — $ — $ 301 $ 301 $ — $ — Equity securities: U.S. Equity 159 159 — — 229 229 — — U.S. Equity fund measured at NAV (a) 340 — — — 364 — — — International equity fund at NAV (a) 466 — — — 538 — — — Commingled debt measured at NAV (a) 543 — — — 611 — — — Debt securities: U.S. Treasury and U.S. government sponsored agency 212 212 — — 186 186 — — Corporate 899 — 874 25 883 — 870 13 Other 17 — 17 — 10 — 10 — Alternative investments: Real estate measured at NAV (a) 90 — — — 109 — — — Private equity measured at NAV (a) 65 — — — 80 — — — Hedge funds measured at NAV (a) 175 — — — 175 — — — December 31, 2018 December 31, 2017 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Derivatives 33 — 33 — 51 — 51 — Insurance contracts 21 — — 21 24 — — 24 PPL Services Corporation Master Trust assets, at fair value 3,240 $ 591 $ 924 $ 46 3,561 $ 716 $ 931 $ 37 Receivables and payables, net (b) (2 ) 72 401(h) accounts restricted for other postretirement benefit obligations (129 ) (145 ) Total PPL Services Corporation Master Trust pension assets $ 3,109 $ 3,488 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2017 is as follows: Corporate debt Insurance contracts Total Balance at beginning of period $ 13 $ 27 $ 40 Actual return on plan assets Relating to assets still held at the reporting date — 1 1 Purchases, sales and settlements — (4 ) (4 ) Balance at end of period $ 13 $ 24 $ 37
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 plan. Pension 2019 $ 25 2020 25 2021 24 2022 23 2023 22 2024-2028 95
Kentucky Utilities Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to KU resulted in liabilities at December 31 as follows. 2018 2017 Pension $ 1 $ 36 Other postretirement benefits 25 32

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2018
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 —
LG And E And KU Energy LLC [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 —
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 —
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2018 and 2017 , the Balance Sheets reflect the owned interests in the facilities listed below. Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress PPL and LKE December 31, 2018 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 77 $ — Trimble County Unit 2 75.00 % 1,063 199 293 December 31, 2017 Generating Plants Trimble County Unit 1 75.00 % $ 427 $ 69 $ 1 Trimble County Unit 2 75.00 % 1,032 176 198 LG&E December 31, 2018 Generating Plants 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 — December 31, 2017 Generating Plants E.W. Brown Units 6-7 38.00 % $ 41 $ 17 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 15 — Trimble County Unit 1 75.00 % 427 69 1 Trimble County Unit 2 14.25 % 215 36 102 Trimble County Units 5-6 29.00 % 32 9 — Trimble County Units 7-10 37.00 % 73 21 — Cane Run Unit 7 22.00 % 120 8 1 E.W. Brown Solar Unit 39.00 % 10 1 — KU December 31, 2018 Generating Plants 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 — Ownership Interest Electric Plant Accumulated Depreciation Construction Work in Progress December 31, 2017 Generating Plants E.W. Brown Units 6-7 62.00 % $ 66 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 13 — Trimble County Unit 2 60.75 % 817 140 96 Trimble County Units 5-6 71.00 % 76 20 — Trimble County Units 7-10 63.00 % 120 34 — Cane Run Unit 7 78.00 % 431 31 4 E.W. Brown Solar Unit 61.00 % 16 1 —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
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 2019 $ 19 $ 8 $ 27 2020 18 8 26 2021 19 8 27 2022 19 8 27 2023 19 8 27 Thereafter 297 133 430 Total $ 391 $ 173 $ 564 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2018 2017 2016 LG&E $ 14 $ 14 $ 16 KU 6 6 7 Total $ 20 $ 20 $ 23 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 2020 Natural Gas Retail Supply 2020 Coal 2023 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026
Guarantees	The table below details guarantees provided as of December 31, 2018 . 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) 2020 WPD guarantee of pension and other obligations of unconsolidated entities 80 (c) PPL Electric Guarantee of inventory value 8 (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, 2018 , 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 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 January 2018, this agreement was superseded by a new contract which extends the guarantee until 2020 . (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 $113 million at December 31, 2018 , consisting of LG&E's share of $78 million and KU's share of $35 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 pro-rata share of certain OVEC obligations of 4.85% filed for bankruptcy under Chapter 11 and, in August 2018, received a rejection Order for the OVEC power purchase contract in the bankruptcy proceeding. OVEC and certain sponsors are appealing this action, in addition to pursuing appropriate rejection claims in the bankruptcy proceeding. 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 proceedings and any other potential impact on LG&E's and KU's obligations relating to OVEC debt 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	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 2020 Natural Gas Retail Supply 2020 Coal 2023 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 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 2019 $ 19 $ 8 $ 27 2020 18 8 26 2021 19 8 27 2022 19 8 27 2023 19 8 27 Thereafter 297 133 430 Total $ 391 $ 173 $ 564 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2018 2017 2016 LG&E $ 14 $ 14 $ 16 KU 6 6 7 Total $ 20 $ 20 $ 23
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 2020 Natural Gas Retail Supply 2020 Coal 2023 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 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 2019 $ 19 $ 8 $ 27 2020 18 8 26 2021 19 8 27 2022 19 8 27 2023 19 8 27 Thereafter 297 133 430 Total $ 391 $ 173 $ 564 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2018 2017 2016 LG&E $ 14 $ 14 $ 16 KU 6 6 7 Total $ 20 $ 20 $ 23
Kentucky Utilities Co [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 2019 $ 19 $ 8 $ 27 2020 18 8 26 2021 19 8 27 2022 19 8 27 2023 19 8 27 Thereafter 297 133 430 Total $ 391 $ 173 $ 564 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2018 2017 2016 LG&E $ 14 $ 14 $ 16 KU 6 6 7 Total $ 20 $ 20 $ 23 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 2020 Natural Gas Retail Supply 2020 Coal 2023 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2018
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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194
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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194
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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194
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. 2018 2017 2016 PPL Electric from PPL Services $ 59 $ 182 $ 132 LKE from PPL Services 26 20 18 PPL Electric from PPL EU Services 148 64 69 LG&E from LKS 151 169 178 KU from LKS 169 190 194

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2018
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL) The breakdown of "Other Income (Expense) - net" for the years ended December 31, was: 2018 2017 2016 Other Income Economic foreign currency exchange contracts (Note 17) $ 150 $ (261 ) $ 384 Defined benefit plans - non-service credits (Note 11) 257 167 112 Interest income 6 2 3 AFUDC - equity component 21 16 19 Miscellaneous 6 17 6 Total Other Income 440 (59 ) 524 2018 2017 2016 Other Expense Charitable contributions 24 8 9 Miscellaneous 20 21 13 Total Other Expense 44 29 22 Other Income (Expense) - net $ 396 $ (88 ) $ 502
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL Electric) The breakdown of "Other Income (Expense) - net" for the years ended December 31, was: 2018 2017 2016 Other Income Interest income $ 2 $ 1 $ 1 AFUDC - equity component 20 15 18 Defined benefit plans - non-service credits (Note 11) 5 1 3 Miscellaneous — — 2 Total Other Income 27 17 24 Other Expense Charitable contribution 3 2 2 Miscellaneous 1 3 2 Total Other Expense 4 5 4 Other Income (Expense) - net $ 23 $ 12 $ 20

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2018
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, 2018 December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 621 $ 621 $ — $ — $ 485 $ 485 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 26 26 — — Special use funds (a) 59 59 — — — — — — Price risk management assets (b): Foreign currency contracts 202 — 202 — 163 — 163 — Cross-currency swaps 135 — 135 — 101 — 101 — Total price risk management assets 337 — 337 — 264 — 264 — Total assets $ 1,039 $ 702 $ 337 $ — $ 775 $ 511 $ 264 $ — December 31, 2018 December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Liabilities Price risk management liabilities (b): Interest rate swaps $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — Foreign currency contracts 2 — 2 — 148 — 148 — Total price risk management liabilities $ 22 $ — $ 22 $ — $ 174 $ — $ 174 $ — PPL Electric Assets Cash and cash equivalents $ 267 $ 267 $ — $ — $ 49 $ 49 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 269 $ 269 $ — $ — $ 51 $ 51 $ — $ — LKE Assets Cash and cash equivalents $ 24 $ 24 $ — $ — $ 30 $ 30 $ — $ — Total assets $ 24 $ 24 $ — $ — $ 30 $ 30 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — LG&E Assets Cash and cash equivalents $ 10 $ 10 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 10 $ 10 $ — $ — $ 15 $ 15 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 20 $ — $ 20 $ — $ 26 $ — $ 26 $ — KU Assets Cash and cash equivalents $ 14 $ 14 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 14 $ 14 $ — $ — $ 15 $ 15 $ — $ — (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) 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, 2018 December 31, 2017 Carrying Fair Value Carrying Fair Value PPL $ 20,599 $ 22,939 $ 20,195 $ 23,783 PPL Electric 3,694 3,901 3,298 3,769 LKE 5,502 5,768 5,159 5,670 LG&E 1,809 1,874 1,709 1,865 KU 2,321 2,451 2,328 2,605

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2018
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, 2018 December 31, 2017 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) 6 — — — 4 — — — Foreign currency contracts — — 103 2 — — 45 67 Total current 6 — 103 6 4 — 45 71 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 16 — — — 22 Cross-currency swaps (b) 129 — — — 97 — — — Foreign currency contracts — — 99 — — — 118 81 Total noncurrent 129 — 99 16 97 — 118 103 Total derivatives $ 135 $ — $ 202 $ 22 $ 101 $ — $ 163 $ 174 (a) Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (b) Excludes accrued interest, if applicable.
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities. Derivative Relationships Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Recognized in Income on Derivative Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing) 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 2016 Cash Flow Hedges: Interest rate swaps $ (21 ) Interest Expense $ (7 ) $ — Cross-currency swaps 130 Other Income (Expense) - net 116 — Interest Expense 3 — Total $ 109 $ 112 $ — Net Investment Hedges: Foreign currency contracts $ 2 Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized in Income on Derivative 2018 2017 2016 Foreign currency contracts Other Income (Expense) - net $ 150 $ (261 ) $ 384 Interest rate swaps Interest Expense (5 ) (6 ) (7 ) Total $ 145 $ (267 ) $ 377 Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets 2018 2017 2016 Interest rate swaps Regulatory assets - noncurrent $ 6 $ 5 $ 7
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, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20 December 31, 2017 Treasury Derivatives PPL $ 264 $ 107 $ 20 $ 137 $ 174 $ 107 $ — $ 67 LKE — — — — 26 — — 26 LG&E — — — — 26 — — 26
Credit Risk-Related Contingent Features	At December 31, 2018 , 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 $ 6 $ 6 $ 6 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) 6 6 6 (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, 2018 December 31, 2017 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 — 16 — 22 Total noncurrent — 16 — 22 Total derivatives $ — $ 20 $ — $ 26
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) 2018 2017 2016 Interest rate swaps Interest Expense $ (5 ) $ (6 ) $ (7 ) Derivative Instruments Location of Gain (Loss) 2018 2017 2016 Interest rate swaps Regulatory assets - noncurrent $ 6 $ 5 $ 7
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, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20 December 31, 2017 Treasury Derivatives PPL $ 264 $ 107 $ 20 $ 137 $ 174 $ 107 $ — $ 67 LKE — — — — 26 — — 26 LG&E — — — — 26 — — 26
Credit Risk-Related Contingent Features	At December 31, 2018 , 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 $ 6 $ 6 $ 6 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) 6 6 6 (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, 2018 December 31, 2017 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 — 16 — 22 Total noncurrent — 16 — 22 Total derivatives $ — $ 20 $ — $ 26
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) 2018 2017 2016 Interest rate swaps Interest Expense $ (5 ) $ (6 ) $ (7 ) Derivative Instruments Location of Gain (Loss) 2018 2017 2016 Interest rate swaps Regulatory assets - noncurrent $ 6 $ 5 $ 7
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, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20 December 31, 2017 Treasury Derivatives PPL $ 264 $ 107 $ 20 $ 137 $ 174 $ 107 $ — $ 67 LKE — — — — 26 — — 26 LG&E — — — — 26 — — 26
Credit Risk-Related Contingent Features	At December 31, 2018 , 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 $ 6 $ 6 $ 6 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) 6 6 6 (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, 2018 Treasury Derivatives PPL $ 337 $ 2 $ 40 $ 295 $ 22 $ 2 $ — $ 20 LKE — — — — 20 — — 20 LG&E — — — — 20 — — 20 December 31, 2017 Treasury Derivatives PPL $ 264 $ 107 $ 20 $ 137 $ 174 $ 107 $ — $ 67 LKE — — — — 26 — — 26 LG&E — — — — 26 — — 26

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2018 2017 2018 2017 2018 2017 Balance at beginning of period (a) $ 2,596 $ 2,398 $ 662 $ 662 $ — $ — $ 3,258 $ 3,060 Effect of foreign currency exchange rates (149 ) 198 — — — — (149 ) 198 Goodwill recognized during the period (b) — — — — 53 — 53 — Balance at end of period (a) $ 2,447 $ 2,596 $ 662 $ 662 $ 53 $ — $ 3,162 $ 3,258 (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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Contracts (a) $ 137 $ 75 $ 138 $ 67 Land rights and easements 418 128 382 120 Licenses and other 21 1 8 3 Total subject to amortization 576 204 528 190 Not subject to amortization due to indefinite life: Land rights and easements 339 — 359 — Other 6 — — — Total not subject to amortization due to indefinite life 345 — 359 — Total $ 921 $ 204 $ 887 $ 190 (a) Gross carrying amount in 2018 and 2017 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: 2018 2017 2016 Intangible assets with no regulatory offset $ 7 $ 6 $ 6 Intangible assets with regulatory offset 8 9 24 Total $ 15 $ 15 $ 30
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 Intangible assets with no regulatory offset $ 7 $ 7 $ 7 $ 7 $ 7 Intangible assets with regulatory offset 9 8 8 8 8 Total $ 16 $ 15 $ 15 $ 15 $ 15
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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 363 $ 121 $ 361 $ 117 Licenses and other 2 1 3 1 Total subject to amortization 365 122 364 118 Not subject to amortization due to indefinite life: Land rights and easements 17 — 13 — Total $ 382 $ 122 $ 377 $ 118
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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 21 $ 3 $ 21 $ 3 OVEC power purchase agreement (a) 126 66 126 58 Total subject to amortization $ 147 $ 69 $ 147 $ 61 (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: 2018 2017 2016 Intangible assets with no regulatory offset $ — $ — $ 1 Intangible assets with regulatory offset 8 9 24 Total $ 8 $ 9 $ 25
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 Intangible assets with regulatory offset $ 9 $ 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, 2018 December 31, 2017 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) 87 46 87 40 Total subject to amortization $ 94 $ 47 $ 94 $ 41 (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: 2018 2017 2016 Intangible assets with regulatory offset $ 6 $ 6 $ 13
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 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, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Subject to amortization: Land rights and easements $ 14 $ 2 $ 14 $ 2 OVEC power purchase agreement (a) 39 20 39 18 Total subject to amortization $ 53 $ 22 $ 53 $ 20 (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: 2018 2017 2016 Intangible assets with no regulatory offset $ — $ — $ 1 Intangible assets with regulatory offset 2 3 11 Total $ 2 $ 3 $ 12
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2019 2020 2021 2022 2023 Intangible assets with regulatory offset $ 3 $ 2 $ 2 $ 2 $ 2

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2018 2017 2018 2017 2018 2017 ARO at beginning of period $ 397 $ 488 $ 356 $ 433 $ 121 $ 145 $ 235 $ 288 Accretion 20 21 18 20 6 7 12 13 Obligations incurred 8 — 8 — — — 8 — Changes in estimated timing or cost (3 ) (73 ) (14 ) (54 ) (2 ) (8 ) (12 ) (46 ) Effect of foreign currency exchange rates (3 ) 4 — — — — — — Obligations settled (72 ) (43 ) (72 ) (43 ) (22 ) (23 ) (50 ) (20 ) ARO at end of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235
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 2018 2017 2018 2017 2018 2017 2018 2017 ARO at beginning of period $ 397 $ 488 $ 356 $ 433 $ 121 $ 145 $ 235 $ 288 Accretion 20 21 18 20 6 7 12 13 Obligations incurred 8 — 8 — — — 8 — Changes in estimated timing or cost (3 ) (73 ) (14 ) (54 ) (2 ) (8 ) (12 ) (46 ) Effect of foreign currency exchange rates (3 ) 4 — — — — — — Obligations settled (72 ) (43 ) (72 ) (43 ) (22 ) (23 ) (50 ) (20 ) ARO at end of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235
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 2018 2017 2018 2017 2018 2017 2018 2017 ARO at beginning of period $ 397 $ 488 $ 356 $ 433 $ 121 $ 145 $ 235 $ 288 Accretion 20 21 18 20 6 7 12 13 Obligations incurred 8 — 8 — — — 8 — Changes in estimated timing or cost (3 ) (73 ) (14 ) (54 ) (2 ) (8 ) (12 ) (46 ) Effect of foreign currency exchange rates (3 ) 4 — — — — — — Obligations settled (72 ) (43 ) (72 ) (43 ) (22 ) (23 ) (50 ) (20 ) ARO at end of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235
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 2018 2017 2018 2017 2018 2017 2018 2017 ARO at beginning of period $ 397 $ 488 $ 356 $ 433 $ 121 $ 145 $ 235 $ 288 Accretion 20 21 18 20 6 7 12 13 Obligations incurred 8 — 8 — — — 8 — Changes in estimated timing or cost (3 ) (73 ) (14 ) (54 ) (2 ) (8 ) (12 ) (46 ) Effect of foreign currency exchange rates (3 ) 4 — — — — — — Obligations settled (72 ) (43 ) (72 ) (43 ) (22 ) (23 ) (50 ) (20 ) ARO at end of period $ 347 $ 397 $ 296 $ 356 $ 103 $ 121 $ 193 $ 235

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2018
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, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the year (1,107 ) 91 — (3 ) (61 ) (1,080 ) Reclassifications from AOCI — (91 ) (1 ) 1 121 30 Net OCI during the year (1,107 ) — (1 ) (2 ) 60 (1,050 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) 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 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 ) 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 ) LKE December 31, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the year — — (27 ) (27 ) Reclassifications from AOCI (1 ) 2 2 3 Net OCI during the year (1 ) 2 (25 ) (24 ) 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 )
Reclassification out of Other Comprehensive Income (Loss)	The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2018 , 2017 and 2016 . PPL Details about AOCI 2018 2017 2016 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (8 ) $ (9 ) $ (7 ) Interest Expense Cross-currency swaps 42 (82 ) 116 Other Income (Expense) - net 1 — 3 Interest Expense Total Pre-tax 35 (91 ) 112 Income Taxes (6 ) 18 (21 ) Total After-tax 29 (73 ) 91 Equity Investees' AOCI — (1 ) 1 Other Income (Expense) - net Total Pre-tax — (1 ) 1 Income Taxes — — — Total After-tax — (1 ) 1 Defined benefit plans Prior service costs (2 ) (2 ) (2 ) Net actuarial loss (178 ) (167 ) (156 ) Total Pre-tax (180 ) (169 ) (158 ) Income Taxes 36 38 36 Total After-tax (144 ) (131 ) (122 ) Total reclassifications during the year $ (115 ) $ (205 ) $ (30 )
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, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the year (1,107 ) 91 — (3 ) (61 ) (1,080 ) Reclassifications from AOCI — (91 ) (1 ) 1 121 30 Net OCI during the year (1,107 ) — (1 ) (2 ) 60 (1,050 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) 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 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 ) 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 ) LKE December 31, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the year — — (27 ) (27 ) Reclassifications from AOCI (1 ) 2 2 3 Net OCI during the year (1 ) 2 (25 ) (24 ) 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 )

New Accounting Guidance Pendi_2

New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Tables)	12 Months Ended
	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Guidance Pending Adoption	The Registrants are expecting amounts recorded on the balance sheet at adoption to be approximately: PPL LKE LGE KU Right of Use Asset $ 80 $ 55 $ 25 $ 30 Current Lease Liability 25 20 10 10 Noncurrent Lease Liability 65 45 15 25
LG And E And KU Energy LLC [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Guidance Pending Adoption	The Registrants are expecting amounts recorded on the balance sheet at adoption to be approximately: PPL LKE LGE KU Right of Use Asset $ 80 $ 55 $ 25 $ 30 Current Lease Liability 25 20 10 10 Noncurrent Lease Liability 65 45 15 25
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Guidance Pending Adoption	The Registrants are expecting amounts recorded on the balance sheet at adoption to be approximately: PPL LKE LGE KU Right of Use Asset $ 80 $ 55 $ 25 $ 30 Current Lease Liability 25 20 10 10 Noncurrent Lease Liability 65 45 15 25
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Guidance Pending Adoption	The Registrants are expecting amounts recorded on the balance sheet at adoption to be approximately: PPL LKE LGE KU Right of Use Asset $ 80 $ 55 $ 25 $ 30 Current Lease Liability 25 20 10 10 Noncurrent Lease Liability 65 45 15 25

Quarterly Financial Information

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 Operating revenues $ 2,126 $ 1,848 $ 1,872 $ 1,939 Operating income 851 658 686 657 Net income (e) 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 Dividends declared per share of common stock (d) 0.41 0.41 0.41 0.41 2017 Operating revenues $ 1,951 $ 1,725 $ 1,845 $ 1,926 Operating income (c) 758 658 736 749 Net income (e) 403 292 355 78 Net income available to PPL common shareowners: (b) Basic EPS 0.59 0.43 0.52 0.11 Diluted EPS 0.59 0.43 0.51 0.11 Dividends declared per share of common stock (d) 0.395 0.395 0.395 0.395 (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. (c) 2017 reflects the retrospective application of new accounting guidance related to the income statement presentation of net periodic benefit costs adopted by PPL in January 2018. See Note 1 to the Financial Statements for additional information on the adoption of this guidance. (d) PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors. (e) Increases in net income for the quarter ended June 30, 2018 compared with June 30, 2017 were primarily due to the favorable impact of foreign currency economic hedges. Increases in net income for the quarter ended December 31, 2018 compared with December 31, 2017 were primarily due to the favorable impact of foreign currency economic hedges in 2018 and the unfavorable impact of U.S. tax reform in 2017.
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 2018 Operating revenues $ 639 $ 517 $ 548 $ 573 Operating income 228 133 178 155 Net income 148 75 111 96 2017 Operating revenues $ 573 $ 500 $ 547 $ 575 Operating income 160 155 189 196 Net income 79 77 95 111 (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, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2018USD ($)IntegerMW	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Utility Revenue (Details) [Abstract]
Domestic electric and gas revenue									$ 5,491	$ 5,351	$ 5,297
U.K. operating revenues									2,268	2,091	2,207
Domestic - other									26	5	13
Operating Revenues	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 1,926	$ 1,845	$ 1,725	$ 1,951	7,785	7,447	7,517
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period									$ 15	11	$ 11
Defined Benefits [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	303				320				$ 303	320
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	98				107				98	107
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	41				43				41	43
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	164				170				$ 164	$ 170
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									2.77%	2.65%	2.73%
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				51				54	$ 51	$ 54	$ 41
Additions charged to income									41	28	44
Additions charged to other accounts									3	(1)	0
Deductions									39	30	31
Balance at end of period	56				51				$ 56	51	54
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
Previous refunded/recovered period of lag for recovery of over and under-recovered amounts									1 year
LGE [Member] | Ohio Valley Electric Corporation [Member]
Investments in Equity Securities [Abstract]
Number of other electric utilities that are equity owners | Integer									10
Number of other companies power is supplied to | Integer									11
Ownership percentage									5.63%
Generation capacity in terms of ownership percentage (in MW) | MW									120
KU [Member] | Ohio Valley Electric Corporation [Member]
Investments in Equity Securities [Abstract]
Number of other electric utilities that are equity owners | Integer									10
Number of other companies power is supplied to | Integer									11
Ownership percentage									2.50%
Generation capacity in terms of ownership percentage (in MW) | MW									53
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	573	$ 548	$ 517	639	575	$ 547	$ 500	573	$ 2,277	2,195	$ 2,156
Property, Plant and Equipment (Numeric) [Abstract]
Regulatory Asset Amortization Period									5 years
Defined Benefits [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)	19				61				$ 19	$ 61
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.01%	2.86%	2.63%
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				24				28	$ 24	$ 28	$ 16
Additions charged to income									29	18	35
Additions charged to other accounts									0	0	0
Deductions									26	22	23
Balance at end of period	27				24				27	24	28
LG And E And KU Energy LLC [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues									$ 3,214	3,156	$ 3,141
Defined Benefits [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)	(16)				(23)				$ (16)	(23)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	248				254				248	254
LG And E And KU Energy LLC [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	98				107				98	107
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	41				43				41	43
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				104				$ 109	$ 104
LG And E And KU Energy LLC [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.69%	3.64%	3.69%
LG And E And KU Energy LLC [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				25				24	$ 25	$ 24	$ 23
Additions charged to income									10	8	8
Additions charged to other accounts									3	(1)	0
Deductions									11	6	7
Balance at end of period	27				25				$ 27	25	24
LG And E And KU Energy LLC [Member] | LGE [Member] | Ohio Valley Electric Corporation [Member]
Investments in Equity Securities [Abstract]
Number of other electric utilities that are equity owners | Integer									10
Number of other companies power is supplied to | Integer									11
Ownership percentage									5.63%
Generation capacity in terms of ownership percentage (in MW) | MW									120
LG And E And KU Energy LLC [Member] | KU [Member] | Ohio Valley Electric Corporation [Member]
Investments in Equity Securities [Abstract]
Number of other electric utilities that are equity owners | Integer									10
Number of other companies power is supplied to | Integer									11
Ownership percentage									2.50%
Generation capacity in terms of ownership percentage (in MW) | MW									53
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues									$ 1,496	1,453	$ 1,430
Defined Benefits [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)	0				0				$ 0	0
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	127				131				127	131
Louisville Gas And Electric Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	42				45				42	45
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	41				43				41	43
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				43				$ 44	$ 43
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.63%	3.63%	3.58%
Louisville Gas And Electric Co [Member] | Ohio Valley Electric Corporation [Member]
Investments in Equity Securities [Abstract]
Number of other electric utilities that are equity owners | Integer									10
Number of other companies power is supplied to | Integer									11
Ownership percentage									5.63%
Generation capacity in terms of ownership percentage (in MW) | MW									120
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				1				2	$ 1	$ 2	$ 1
Additions charged to income									4	2	2
Additions charged to other accounts									1	(1)	1
Deductions									5	2	2
Balance at end of period	1				1				1	1	2
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues									$ 1,760	1,744	$ 1,749
Defined Benefits [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization									30.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis									10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis									30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized									50.00%
Intercompany tax receivables (payables)	(5)				0				$ (5)	0
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	121				123				121	123
Kentucky Utilities Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	56				62				56	62
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				61				$ 65	$ 61
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates									3.74%	3.66%	3.77%
Kentucky Utilities Co [Member] | Ohio Valley Electric Corporation [Member]
Investments in Equity Securities [Abstract]
Number of other electric utilities that are equity owners | Integer									10
Number of other companies power is supplied to | Integer									11
Ownership percentage									2.50%
Generation capacity in terms of ownership percentage (in MW) | MW									53
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period				$ 1				$ 2	$ 1	$ 2	$ 2
Additions charged to income									5	4	4
Additions charged to other accounts									2	(1)	0
Deductions									6	4	4
Balance at end of period	$ 2				$ 1				$ 2	$ 1	$ 2

New Accounting Guidance Adopted

New Accounting Guidance Adopted (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	$ 621	$ 485
Total Cash, Cash Equivalents and Restricted Cash	643	511	$ 372	$ 875
Defined benefit plans - non-service credits	257	167	112
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(51)
Accounting Standards Update 2016-18 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	621	485
Restricted cash - current	3	3
Restricted cash - noncurrent	19	23
Total Cash, Cash Equivalents and Restricted Cash	643	511
Accounting Standards Update 2017-07 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Defined Benefit Plan Net Periodic Benefit Cost - Non-Service Cost Previously Capitalized Due To ASU 2017-07 - Before Tax	22
Defined Benefit Plan Net Periodic Benefit Cost - Non-Service Cost Previously Capitalized Due To ASU 2017-07 - After Tax	$ 17
Defined Benefit Plan Net Periodic Benefit Cost - Non-Service Cost Previously Capitalized Due to ASU 2017-07 - Per Share	$ 0.02
Defined benefit plans - non-service credits	$ 257	167	112
Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	51
PPL Electric Utilities Corp [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	267	49
Total Cash, Cash Equivalents and Restricted Cash	269	51	15	49
Defined benefit plans - non-service credits	5	1	3
PPL Electric Utilities Corp [Member] | Accounting Standards Update 2016-18 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	267	49
Restricted cash - current	2	2
Restricted cash - noncurrent	0	0
Total Cash, Cash Equivalents and Restricted Cash	269	51
PPL Electric Utilities Corp [Member] | Accounting Standards Update 2017-07 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Defined benefit plans - non-service credits	5	1	3
LG And E And KU Energy LLC [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	24	30	13	30
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(18)
LG And E And KU Energy LLC [Member] | Accounting Standards Update 2017-07 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Defined benefit plans - non-service credits	4	(5)	(6)
LG And E And KU Energy LLC [Member] | Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	18
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	10	15	5	19
Louisville Gas And Electric Co [Member] | Accounting Standards Update 2017-07 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Defined benefit plans - non-service credits	(2)	(5)	(5)
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents	14	15	7	$ 11
Kentucky Utilities Co [Member] | Accounting Standards Update 2017-07 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Defined benefit plans - non-service credits	$ 3	$ (1)	$ (2)

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, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2018USD ($)Integer		Dec. 31, 2017USD ($)		Dec. 31, 2016USD ($)
Income Statement Data
Operating Revenues from external customers		$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 1,926	$ 1,845	$ 1,725	$ 1,951	$ 7,785		$ 7,447		$ 7,517
Depreciation										1,094		1,008		926
Amortization										78		97		80
Unrealized (gains) losses on derivatives and other hedging activities										(186)		178		19
Interest Expense										963		901		888
Income Before Income Taxes										2,285		1,912		2,550
Income Taxes										458		784		648
Deferred income taxes and investment tax credits										355		707		560
Net income		415	445	515	452	78	355	292	403	1,827		1,128		1,902
Cash Flow Data
Expenditures for long-lived assets										3,268		3,171		2,957
Balance Sheet Data
Total Assets		43,396				41,479				$ 43,396		41,479
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer										3
U.K. Regulated [Member]
Income Statement Data
Operating Revenues from external customers										$ 2,268		2,091		2,207
Depreciation										247		230		233
Amortization										34		34		16
Unrealized (gains) losses on derivatives and other hedging activities										(190)		166		13
Interest Expense										413		397		402
Income Before Income Taxes										1,339		804		1,479
Income Taxes										225		152		233
Deferred income taxes and investment tax credits										118		66		31
Net income										1,114		652		1,246
Cash Flow Data
Expenditures for long-lived assets										954		1,015		1,031
Balance Sheet Data
Total Assets		16,700				16,813				16,700		16,813
Segment Information (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		12,400				12,500				12,400		12,500
Kentucky Regulated [Member]
Income Statement Data
Operating Revenues from external customers										3,214		3,156		3,141
Depreciation										475		439		404
Amortization										18		24		29
Unrealized (gains) losses on derivatives and other hedging activities										6		6		6
Interest Expense										274		261		260
Income Before Income Taxes										531		645		640
Income Taxes										120		359		242
Deferred income taxes and investment tax credits										94		294		291
Net income										411		286		398
Cash Flow Data
Expenditures for long-lived assets										1,117		892		791
Balance Sheet Data
Total Assets		15,078				14,468				15,078		14,468
Pennsylvania Regulated [Member]
Income Statement Data
Operating Revenues from external customers										2,277		2,195		2,156
Depreciation										352		309		253
Amortization										22		33		32
Interest Expense										159		142		129
Income Before Income Taxes										567		575		550
Income Taxes										136		216		212
Deferred income taxes and investment tax credits										125		257		221
Net income										431		359		338
Cash Flow Data
Expenditures for long-lived assets										1,196		1,254		1,134
Balance Sheet Data
Total Assets		11,257				10,082				11,257		10,082
Corporate And Other [Member]
Income Statement Data
Operating Revenues from external customers										26		5		13
Depreciation										20		30		36
Amortization										4		6		3
Unrealized (gains) losses on derivatives and other hedging activities										(2)		6		0
Interest Expense										117		101		97
Income Before Income Taxes										(152)		(112)		(119)
Income Taxes										(23)		57		(39)
Deferred income taxes and investment tax credits										18		90		17
Net income										(129)		(169)		(80)
Cash Flow Data
Expenditures for long-lived assets										1		10		1
Balance Sheet Data
Total Assets		361				116				361		116
PPL Electric Utilities Corp [Member]
Income Statement Data
Operating Revenues from external customers		573	548	517	639	575	547	500	573	2,277		2,195		2,156
Depreciation										352		309		253
Amortization										22		33		32
Interest Expense										159		142		129
Income Before Income Taxes										566		575		552
Income Taxes										136		213		212
Deferred income taxes and investment tax credits										125		258		221
Net income		96	$ 111	$ 75	$ 148	111	$ 95	$ 77	$ 79	430	[1]	362	[1]	340	[1]
Balance Sheet Data
Total Assets		11,243				10,082				$ 11,243		10,082
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										$ 3,214		3,156		3,141
Depreciation										475		439		404
Amortization										18		24		29
Interest Expense										206		197		197
Income Before Income Taxes										574		691		686
Income Taxes										129		375		257
Deferred income taxes and investment tax credits										94		294		291
Net income										445		316		429
Balance Sheet Data
Total Assets		15,412				14,802				$ 15,412		14,802
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										$ 1,496		1,453		1,430
Depreciation										195		183		170
Amortization										14		14		14
Interest Expense										76		71		71
Income Before Income Taxes										297		344		329
Income Taxes										64		131		126
Deferred income taxes and investment tax credits										60		126		147
Net income	[2]									233		213		203
Balance Sheet Data
Total Assets		6,883				6,559				$ 6,883		6,559
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										$ 1,760		1,744		1,749
Depreciation										279		255		234
Amortization										3		9		14
Interest Expense										100		96		96
Income Before Income Taxes										362		418		428
Income Taxes										76		159		163
Deferred income taxes and investment tax credits										48		152		126
Net income	[3]									286		259		$ 265
Balance Sheet Data
Total Assets		$ 8,540				$ 8,254				$ 8,540		$ 8,254
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, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 1,926	$ 1,845	$ 1,725	$ 1,951	$ 7,785	$ 7,447	$ 7,517
Long-lived assets	35,175				33,787				35,175	33,787
U.S. [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers									5,517	5,356	5,310
Long-lived assets	22,384				20,936				22,384	20,936
U.K. [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	$ 12,791				$ 12,851				12,791	12,851
U.K. Regulated [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers									$ 2,268	$ 2,091	$ 2,207

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2018USD ($)Days	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 1,926	$ 1,845	$ 1,725	$ 1,951	$ 7,785	$ 7,447	$ 7,517
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									32
Other Revenue									(38)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									7,779
Credit loss from contract with customer [Abstract]
Provision for Doubtful Accounts									34
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	42				29				42	29
Contract with Customer, Liability, Revenue Recognized									21
Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									2,127
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									2,704
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,233
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									624
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									489
Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									118
Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									79
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									405
Pennsylvania Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 2,277	2,195	2,156
Number Of Days Due From Invoice Date | Days									21
U.K. Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 2,268	2,091	2,207
Number Of Days Due From Invoice Date | Days									14
Kentucky Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 3,214	3,156	3,141
Number Of Days Due From Invoice Date | Days									22
Corporate Segment [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 26	5	13
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability, Revenue Recognized									$ 37
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]: 2019-01-01 | Corporate Segment [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 49								$ 49
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	12 months								12 months
PPL Electric Utilities Corp [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 573	$ 548	$ 517	$ 639	575	$ 547	$ 500	$ 573	$ 2,277	2,195	2,156
Number Of Days Due From Invoice Date | Days									21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									$ (6)
Other Revenue									(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									2,259
Credit loss from contract with customer [Abstract]
Provision for Doubtful Accounts									24
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	23				19				23	19
Contract with Customer, Liability, Revenue Recognized									8
PPL Electric Utilities Corp [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,379
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									368
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									54
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									53
PPL Electric Utilities Corp [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
PPL Electric Utilities Corp [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
PPL Electric Utilities Corp [Member] | Distribution [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,900
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									405
LG And E And KU Energy LLC [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									3,214	3,156	3,141
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									38
Other Revenue									(17)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									3,235
Credit loss from contract with customer [Abstract]
Provision for Doubtful Accounts									9
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	9				8				9	8
Contract with Customer, Liability, Revenue Recognized									8
LG And E And KU Energy LLC [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
LG And E And KU Energy LLC [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,325
LG And E And KU Energy LLC [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									865
LG And E And KU Energy LLC [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									570
LG And E And KU Energy LLC [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									278
LG And E And KU Energy LLC [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									118
LG And E And KU Energy LLC [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									79
LG And E And KU Energy LLC [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									$ 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									$ 1,496	1,453	1,430
Number Of Days Due From Invoice Date | Days									22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									$ 12
Other Revenue									(5)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,503
Credit loss from contract with customer [Abstract]
Provision for Doubtful Accounts									4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	5				4				5	4
Contract with Customer, Liability, Revenue Recognized									4
Louisville Gas And Electric Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									666
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									455
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									180
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									129
Louisville Gas And Electric Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
Louisville Gas And Electric Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									73
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
Kentucky Utilities Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues									$ 1,760	1,744	$ 1,749
Number Of Days Due From Invoice Date | Days									22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs									$ 26
Other Revenue									(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									1,774
Credit loss from contract with customer [Abstract]
Provision for Doubtful Accounts									5
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	$ 4				$ 4				4	$ 4
Contract with Customer, Liability, Revenue Recognized									4
Kentucky Utilities Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									0
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									659
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									410
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									390
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									149
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									118
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									48
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers									$ 0

Preferred Securities (Details)

Preferred Securities (Details) - $ / shares	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
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, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income (Numerator)
Less amounts allocated to participating securities									$ 2	$ 2	$ 6
Net income available to PPL common shareowners - Basic									1,825	1,126	1,896
Net income	$ 415	$ 445	$ 515	$ 452	$ 78	$ 355	$ 292	$ 403	1,827	1,128	1,902
Net income available to PPL common shareowners - Diluted									$ 1,825	$ 1,126	$ 1,896
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)									704,439	685,240	677,592
Add incremental non-participating securities:
Share-based payment awards (in shares)									445	2,094	2,854
Forward sales agreements									3,735	0	0
Weighted-average shares - Diluted EPS (in shares)									708,619	687,334	680,446
Basic EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 0.57	$ 0.63	$ 0.74	$ 0.65	$ 0.11	$ 0.52	$ 0.43	$ 0.59	$ 2.59	$ 1.64	$ 2.80
Diluted EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 0.57	$ 0.62	$ 0.73	$ 0.65	$ 0.11	$ 0.51	$ 0.43	$ 0.59	$ 2.58	$ 1.64	$ 2.79
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)									720
Common stock issued under DRIP (in shares)									1,974
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS									172	696	696
Performance Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS									0	0	176
Restricted Stock Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS									11	0	0

Income and Other Taxes (Tax Ref

Income and Other Taxes (Tax Reform) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 458	$ 784	$ 648
Net Increase in Regulatory Liability	(13)	12	59
Deferred Tax Liabilities, Net	2,768	2,438
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)	136	213	212
Net Increase in Regulatory Liability	19	5	62
Deferred Tax Liabilities, Net	1,320	1,154
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)	129	375	257
Net Increase in Regulatory Liability	(32)	7	(1)
Deferred Tax Liabilities, Net	956	866
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)	64	131	126
Net Increase in Regulatory Liability	(5)	5	1
Deferred Tax Liabilities, Net	628	572
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)	76	159	163
Net Increase in Regulatory Liability	(27)	2	$ (2)
Deferred Tax Liabilities, Net	735	691
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, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Before Income Taxes (Details) [Abstract]
Domestic income	$ 1,127	$ 874	$ 1,463
Foreign income	1,158	1,038	1,087
Income Before Income Taxes	2,285	1,912	2,550
Deferred Tax Assets
Deferred investment tax credits	31	33
Regulatory liabilities	87	68
Income taxes due to customer	479	499
Accrued pension and postretirement costs	277	232
Federal loss carryforwards	325	356
State loss carryforwards	419	409
Federal and state tax credit carryforwards	392	455
Foreign capital loss carryforwards	313	329
Foreign loss carryforwards	1	2
Foreign - regulatory obligations	0	2
Foreign - other	9	7
Contributions in aid of construction	139	134
Domestic - other	81	102
Unrealized losses on qualifying derivatives	7	10
Valuation allowances	(808)	(838)
Total deferred tax assets	1,752	1,800
Deferred Tax Liabilities
Domestic plant - net	3,359	3,168
Regulatory assets	314	288
Reacquired debt costs	12	15
Foreign plant - net	724	726
Foreign - pensions	83	32
Domestic - other	28	9
Total deferred tax liabilities	4,520	4,238
Net deferred tax liability	2,768	2,438
Loss carryforwards
Federal loss carryforwards	325	356
State loss carryforwards	419	409
Foreign loss carryforwards	1	2
Foreign capital loss carryforwards	313	329
Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	319
Loss carryforwards
Net operating losses	1,519
Charitable contributions	29
Federal loss carryforwards	319
Charitable contribution carryforwards	6
Loss carryforward valuation allowance on net operating losses	0
Charitable Contributions Loss Carryforwards valuation allowance	0
State [Member]
Deferred Tax Assets
State loss carryforwards	418
Loss carryforwards
Net operating losses	5,725
Charitable contributions	7
State loss carryforwards	418
Charitable contribution carryforwards	1
Loss carryforward valuation allowance on net operating losses	(370)
Charitable Contributions Loss Carryforwards valuation allowance	0
Foreign Tax Authority [Member]
Deferred Tax Assets
Foreign capital loss carryforwards	313
Foreign loss carryforwards	1
Loss carryforwards
Net operating losses	6
Capital losses	1,842
Foreign loss carryforwards	1
Foreign capital loss carryforwards	313
Loss carryforward valuation allowance on net operating losses	0
Loss carryforward valuation allowance on capital losses	(313)
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	$ 28	24
Minimum [Member] | Federal [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2031
Expiration - charitable contributions	Dec. 31, 2020
Minimum [Member] | State [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2019
Expiration - charitable contributions	Dec. 31, 2020
Maximum [Member] | Federal [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2037
Expiration - charitable contributions	Dec. 31, 2022
Maximum [Member] | State [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2038
Expiration - charitable contributions	Dec. 31, 2022
PPL Electric Utilities Corp [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	$ 566	575	552
Deferred Tax Assets
Regulatory liabilities	35	25
Income taxes due to customer	181	193
Accrued pension and postretirement costs	110	81
Federal loss carryforwards	79	91
State loss carryforwards	14	19
Contributions in aid of construction	118	117
Domestic - other	25	27
Total deferred tax assets	562	553
Deferred Tax Liabilities
Domestic plant - net	1,681	1,544
Regulatory assets	176	150
Reacquired debt costs	6	8
Domestic - other	19	5
Total deferred tax liabilities	1,882	1,707
Net deferred tax liability	1,320	1,154
Loss carryforwards
Federal loss carryforwards	79	91
State loss carryforwards	14	19
PPL Electric Utilities Corp [Member] | Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	78
Loss carryforwards
Net operating losses	370
Charitable contributions	6
Federal loss carryforwards	78
Charitable contribution carryforwards	1
PPL Electric Utilities Corp [Member] | State [Member]
Deferred Tax Assets
State loss carryforwards	14
Loss carryforwards
Net operating losses	180
Charitable contributions	5
State loss carryforwards	14
Charitable contribution carryforwards	$ 0
PPL Electric Utilities Corp [Member] | Minimum [Member] | Federal [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2031
Expiration - charitable contributions	Dec. 31, 2020
PPL Electric Utilities Corp [Member] | Minimum [Member] | State [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2031
Expiration - charitable contributions	Dec. 31, 2020
PPL Electric Utilities Corp [Member] | Maximum [Member] | Federal [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2037
Expiration - charitable contributions	Dec. 31, 2022
PPL Electric Utilities Corp [Member] | Maximum [Member] | State [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2032
Expiration - charitable contributions	Dec. 31, 2022
LG And E And KU Energy LLC [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	$ 574	691	686
Deferred Tax Assets
Deferred investment tax credits	32	33
Regulatory liabilities	52	43
Income taxes due to customer	299	305
Accrued pension and postretirement costs	92	100
Federal loss carryforwards	142	150
State loss carryforwards	33	41
Federal and state tax credit carryforwards	169	181
Contributions in aid of construction	21	17
Domestic - other	29	33
Valuation allowances	(8)	(8)
Total deferred tax assets	861	895
Deferred Tax Liabilities
Domestic plant - net	1,671	1,615
Regulatory assets	138	138
Domestic - other	8	8
Total deferred tax liabilities	1,817	1,761
Net deferred tax liability	956	866
Loss carryforwards
Federal loss carryforwards	142	150
State loss carryforwards	33	41
LG And E And KU Energy LLC [Member] | Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	142
Loss carryforwards
Net operating losses	674
Charitable contributions	11
Federal loss carryforwards	142
Charitable contribution carryforwards	2
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	33
Loss carryforwards
Net operating losses	848
State loss carryforwards	33
Loss carryforward valuation allowance on net operating losses	$ 0
LG And E And KU Energy LLC [Member] | Minimum [Member] | Federal [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2031
Expiration - charitable contributions	Dec. 31, 2020
LG And E And KU Energy LLC [Member] | Minimum [Member] | State [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2029
LG And E And KU Energy LLC [Member] | Maximum [Member] | Federal [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2037
Expiration - charitable contributions	Dec. 31, 2022
LG And E And KU Energy LLC [Member] | Maximum [Member] | State [Member]
Loss carryforwards
Expiration - operating losses	Dec. 31, 2038
Louisville Gas And Electric Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	$ 297	344	329
Deferred Tax Assets
Deferred investment tax credits	9	9
Regulatory liabilities	24	21
Income taxes due to customer	139	142
Accrued pension and postretirement costs	16	14
Federal loss carryforwards	0	29
Contributions in aid of construction	14	11
Domestic - other	15	19
Total deferred tax assets	217	245
Deferred Tax Liabilities
Domestic plant - net	751	724
Regulatory assets	88	88
Domestic - other	6	5
Total deferred tax liabilities	845	817
Net deferred tax liability	628	572
Loss carryforwards
Federal loss carryforwards	0	29
Kentucky Utilities Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	362	418	$ 428
Deferred Tax Assets
Deferred investment tax credits	23	24
Regulatory liabilities	28	22
Income taxes due to customer	160	163
Accrued pension and postretirement costs	7	7
Federal loss carryforwards	0	13
Contributions in aid of construction	7	6
Domestic - other	3	8
Total deferred tax assets	228	243
Deferred Tax Liabilities
Domestic plant - net	911	882
Regulatory assets	50	50
Domestic - other	2	2
Total deferred tax liabilities	963	934
Net deferred tax liability	735	691
Loss carryforwards
Federal loss carryforwards	$ 0	$ 13

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Credit carryforwards
Deferred tax asset credit carryforwards	$ 392	$ 455
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	6,700
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
Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2025
Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2036
Alternative Minimum Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	$ 15
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
Foreign Tax Credit [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2024
Foreign Tax Credit [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2027
Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	$ 25
Credit Carryforward Valuation Allowance Other	$ (8)
Other [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2019
Other [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2038
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	838	593	$ 662
Additions charged to income	26	256	17
Additions charged to other accounts	0	0	2
Deductions	56	11	88
Balance at end of period	808	838	593
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		65
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
Reduction of the valuation allowance as a result of the reduction in the UK statutory income tax rate			19
LG And E And KU Energy LLC [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	169	181
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] | Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2025
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2036
LG And E And KU Energy LLC [Member] | Alternative Minimum Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	$ 14
Credit Carryforward Valuation Allowance Alternative Minimum Tax Credit	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	$ (8)
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2019
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2038
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	11	12
Additions charged to other accounts	0	4	0
Deductions	0	7	1
Balance at end of period	8	$ 8	$ 11
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	$ 6
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2036
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Tax Credit Carryforward Expiration Date 1	Dec. 31, 2038

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Expense (Benefit)
Current - Federal	$ (19)	$ 6	$ (14)
Current - State	17	25	21
Current - Foreign	104	45	80
Total Current Expense	102	76	87
Deferred - Federal	203	532	385
Deferred - State	100	88	89
Deferred - Foreign	107	133	86
Total Deferred Expense (Benefit), excluding operating loss carry forwards	410	753	560
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	(20)	(16)	25
Deferred - State	(31)	(26)	(21)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(51)	(42)	4
Total income tax from continuing operations	458	784	648
Income tax expense [Abstract]
Total income tax expense - Federal	161	519	393
Total income tax expense - State	86	87	89
Total income tax expense - Foreign	211	178	166
Total income tax from continuing operations	458	784	648
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Stock-based compensation recorded to Earnings Reinvested	0	0	(7)
Other comprehensive income	(6)	(34)	(6)
Valuation allowance on state deferred taxes recorded to other comprehensive income	0	(1)	1
Total income tax expense (benefits) excluded from incomes taxes from continuing operations	(6)	(35)	(12)
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	480	669	893
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	40	46	46
Valuation allowance adjustments	21	36	16
Impact of lower U.K. income tax rates	(25)	(176)	(177)
U.S. income tax on foreign earnings - net of foreign tax credit	3	47	(42)
Foreign income return adjustments	0	(8)	2
Impact of the United Kingdom Finance Acts on deferred tax balances	(13)	(16)	(49)
Depreciation and other items not normalized	(11)	(10)	(10)
Amortization of excess deferred federal and state income taxes	(37)	0	0
Interest benefit on United Kingdom financing entities	(17)	(16)	(17)
Stock-based compensation	4	(3)	(10)
Deferred tax impact of U.S. tax reform	0	220	0
Deferred tax impact of Kentucky tax reform	9	0	0
Other	4	(5)	(4)
Total increase (decrease)	(22)	115	(245)
Total income tax from continuing operations	$ 458	$ 784	$ 648
Effective income tax rate	20.00%	41.00%	25.40%
Income Tax Reconciliation Valuation Allowance Foreign Tax Credits		$ 23
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized	$ 24	16	$ 13
Deferred Income Tax Expense Benefit Statutory Tax Rate Change			(42)
Deferred Income Tax Expense Benefit Foreign Pension Contribution		35
Taxes, other than income
State gross receipts	103	102	100
State capital stock	0	(6)	0
Foreign property	134	127	135
Domestic property and other	75	69	66
Total	312	292	301
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	2	(65)	(29)
Current - State	9	20	19
Total Current Expense	11	(45)	(10)
Deferred - Federal	96	234	193
Deferred - State	37	29	29
Total Deferred Expense (Benefit), excluding operating loss carry forwards	133	263	222
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	(8)	(5)	0
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(8)	(5)	0
Total income tax from continuing operations	136	213	212
Income tax expense [Abstract]
Total income tax expense - Federal	90	164	164
Total income tax expense - State	46	49	48
Total income tax from continuing operations	136	213	212
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	119	201	193
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	43	36	36
Depreciation and other items not normalized	(11)	(8)	(8)
Amortization of excess deferred federal and state income taxes	(17)	0	0
Stock-based compensation	1	(2)	(6)
Deferred tax impact of U.S. tax reform	0	(13)	0
Other	1	(1)	(3)
Total increase (decrease)	17	12	19
Total income tax from continuing operations	$ 136	$ 213	$ 212
Effective income tax rate	24.00%	37.00%	38.40%
Taxes, other than income
State gross receipts	$ 103	$ 102	$ 100
Domestic property and other	6	5	5
Total	109	107	105
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	31	74	(36)
Current - State	4	6	1
Total Current Expense	35	80	(35)
Deferred - Federal	65	268	248
Deferred - State	34	32	38
Total Deferred Expense (Benefit), excluding operating loss carry forwards	99	300	286
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	(2)	(2)	10
Deferred - State	0	0	(1)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(2)	(2)	9
Total income tax from continuing operations	129	375	257
Income tax expense [Abstract]
Total income tax expense - Federal	91	337	219
Total income tax expense - State	38	38	38
Total income tax from continuing operations	129	375	257
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Other comprehensive income	5	(10)	(16)
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	121	242	240
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	22	26	26
Valuation allowance adjustments	(20)	(2)	(1)
Amortization of investment tax credit	(3)	(3)	(3)
Stock-based compensation	1	1	(3)
Deferred tax impact of U.S. tax reform	0	112	0
Deferred tax impact of Kentucky tax reform	9	0	0
Other	(1)	(1)	(2)
Total increase (decrease)	8	133	17
Total income tax from continuing operations	$ 129	$ 375	$ 257
Effective income tax rate	22.50%	54.30%	37.50%
Taxes, other than income
Domestic property and other	$ 70	$ 65	$ 62
Total	70	65	62
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	0	0	(22)
Current - State	4	5	1
Total Current Expense	4	5	(21)
Deferred - Federal	51	112	134
Deferred - State	10	14	18
Total Deferred Expense (Benefit), excluding operating loss carry forwards	61	126	152
Amortization of investment tax credit	(1)	(1)	(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	1	(4)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	1	(4)
Total income tax from continuing operations	64	131	126
Income tax expense [Abstract]
Total income tax expense - Federal	50	112	107
Total income tax expense - State	14	19	19
Total income tax from continuing operations	64	131	126
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	62	120	115
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	11	14	12
Amortization of investment tax credit	(1)	(1)	(1)
Amortization of excess deferred federal and state income taxes	(8)	(1)	0
Other	0	(1)	0
Total increase (decrease)	2	11	11
Total income tax from continuing operations	$ 64	$ 131	$ 126
Effective income tax rate	21.50%	38.10%	38.30%
Taxes, other than income
Domestic property and other	$ 36	$ 33	$ 32
Total	36	33	32
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	22	0	31
Current - State	6	7	5
Total Current Expense	28	7	36
Deferred - Federal	40	138	131
Deferred - State	10	16	19
Total Deferred Expense (Benefit), excluding operating loss carry forwards	50	154	150
Amortization of investment tax credit	(2)	(2)	(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	0	(21)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	0	(21)
Total income tax from continuing operations	76	159	163
Income tax expense [Abstract]
Total income tax expense - Federal	60	136	139
Total income tax expense - State	16	23	24
Total income tax from continuing operations	76	159	163
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	76	146	150
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	13	15	16
Amortization of investment tax credit	(2)	(2)	(2)
Amortization of excess deferred federal and state income taxes	(12)	(1)	(1)
Other	1	1	0
Total increase (decrease)	0	13	13
Total income tax from continuing operations	$ 76	$ 159	$ 163
Effective income tax rate	21.00%	38.00%	38.10%
Taxes, other than income
Domestic property and other	$ 34	$ 32	$ 30
Total	$ 34	32	$ 30
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, 2018USD ($)Integer	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	4
Deferred Income Tax Expense (Benefit)	$ 410	$ 753	$ 560
Increase (Decrease) in Regulatory Assets and Liabilities	$ (13)	12	59
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2013 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2013 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)	$ 133	263	222
Increase (Decrease) in Regulatory Assets and Liabilities	$ 19	5	62
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2013 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	2011 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)	$ 99	300	286
Increase (Decrease) in Regulatory Assets and Liabilities	$ (32)	7	(1)
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	2013 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	2013 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)	$ 61	126	152
Increase (Decrease) in Regulatory Assets and Liabilities	$ (5)	5	1
Louisville Gas And Electric Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2013 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	2013 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)	$ 50	154	150
Increase (Decrease) in Regulatory Assets and Liabilities	$ (27)	$ 2	$ (2)
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2013 and prior
Kentucky Utilities Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2013 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, 2018	Dec. 31, 2017
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 36	$ 34
Noncurrent Regulatory Assets	1,673	1,504
Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	5
Generation formula rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	6
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	12	4
Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	11	15
Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	10	3
Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	3	1
Noncurrent Regulatory Assets	7	9
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	963	880
Taxes recoverable through future rates [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	3	3
Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	56	33
Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	45	54
Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	20	26
Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	87	92
Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	200	173
AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	273	234
Act 129 compliance rider [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	19	0
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	11	16
Noncurrent Regulatory Assets	824	709
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Generation formula rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	11	15
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	1
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	558	504
PPL Electric Utilities Corp [Member] | Taxes recoverable through future rates [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	3	3
PPL Electric Utilities Corp [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	0
PPL Electric Utilities Corp [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	29
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	200	173
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	19	0
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	25	18
Noncurrent Regulatory Assets	849	795
LG And E And KU Energy LLC [Member] | Generation formula rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	6
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	12	4
LG And E And KU Energy LLC [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	10	3
LG And E And KU Energy LLC [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	3	5
Noncurrent Regulatory Assets	7	9
LG And E And KU Energy LLC [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	405	376
LG And E And KU Energy LLC [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	34	33
LG And E And KU Energy LLC [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	23	25
LG And E And KU Energy LLC [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	20	26
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	87	92
LG And E And KU Energy LLC [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	273	234
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	21	12
Noncurrent Regulatory Assets	431	411
Louisville Gas And Electric Co [Member] | Generation formula rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	12	4
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	7	3
Louisville Gas And Electric Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	2	5
Noncurrent Regulatory Assets	1	2
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	249	234
Louisville Gas And Electric Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	20	18
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	15	16
Louisville Gas And Electric Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	20	26
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	51	54
Louisville Gas And Electric Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	75	61
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	6
Noncurrent Regulatory Assets	418	384
Kentucky Utilities Co [Member] | Generation formula rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	6
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	3	0
Kentucky Utilities Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	1	0
Noncurrent Regulatory Assets	6	7
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	156	142
Kentucky Utilities Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	14	15
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	8	9
Kentucky Utilities Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	36	38
Kentucky Utilities Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 198	$ 173

Utility Rate Regulation (Regu_2

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 122	$ 95
Noncurrent regulatory liabilities	2,714	2,704
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	33	34
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	9
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	16	1
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	27	26
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	9
TCJA surcredit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	20	0
Noncurrent regulatory liabilities	41	0
Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	8
Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	674	677
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	59	68
Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,826	1,853
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	37	27
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	74
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	15	8
Noncurrent regulatory liabilities	5	5
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	74	86
Noncurrent regulatory liabilities	675	668
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	33	34
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	9
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	27	26
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	9
PPL Electric Utilities Corp [Member] | TCJA surcredit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	0
Noncurrent regulatory liabilities	41
PPL Electric Utilities Corp [Member] | Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	8
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 Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	629	668
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	5	0
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	48	9
Noncurrent regulatory liabilities	2,039	2,036
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	16	1
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3
LG And E And KU Energy LLC [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	2	3
LG And E And KU Energy LLC [Member] | TCJA surcredit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	0
LG And E And KU Energy LLC [Member] | Generation formula rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
LG And E And KU Energy LLC [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	674	677
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	59	68
LG And E And KU Energy LLC [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,197	1,185
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	32	27
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	74
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	2
Noncurrent regulatory liabilities	5	5
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	3
Noncurrent regulatory liabilities	915	919
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	2	3
Louisville Gas And Electric Co [Member] | TCJA surcredit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
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	279	282
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	41	47
Louisville Gas And Electric Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	557	552
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	36	37
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	0
Noncurrent regulatory liabilities	2	1
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	31	6
Noncurrent regulatory liabilities	1,124	1,117
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	10	1
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3
Kentucky Utilities Co [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	0	0
Kentucky Utilities Co [Member] | TCJA surcredit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	10	0
Kentucky Utilities Co [Member] | Generation formula rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	395	395
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	18	21
Kentucky Utilities Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	640	633
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	32	27
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	36	37
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	2
Noncurrent regulatory liabilities	$ 3	$ 4

Utility Rate Regulation (Regu_3

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)Customer	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ (13)	$ 12	$ 59
Accounting Standards Update 2017-07 [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Assets	1
Accounting Standards Update 2017-07 [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Liabilities	$ 11
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 (Numeric) [Line Items]
Amortization end date	Dec. 31, 2021
Regulatory Assets and Liabilities - Storm Costs (Numeric) [Abstract]
Period over which storm costs will be recovered (in years)	3 years
PPL Electric [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2029
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	$ 45	33
LKE [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2044
LKE [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Mar. 31, 2026
LGE [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2044
LGE [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period	12 months
LGE [Member] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2033
LGE [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.70%
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	9.70%
KU [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Number of Municipal Customers | Customer	10
KU [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2042
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	9.70%
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	$ 19	5	62
PPL Electric Utilities Corp [Member] | Accounting Standards Update 2017-07 [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Liabilities	$ 5
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2021
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] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2029
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	(32)	7	(1)
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps	0	0	(9)
LG And E And KU Energy LLC [Member] | Accounting Standards Update 2017-07 [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Liabilities	6
Regulatory Assets	$ 1
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	$ 45	33
LG And E And KU Energy LLC [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2044
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Mar. 31, 2026
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] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2033
LG And E And KU Energy LLC [Member] | LGE [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.70%
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	9.70%
LG And E And KU Energy LLC [Member] | KU [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Number of Municipal Customers | Customer	10
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	9.70%
Louisville Gas And Electric Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ (5)	5	1
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps	0	0	(9)
Louisville Gas And Electric Co [Member] | Accounting Standards Update 2017-07 [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Assets	$ 1
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	$ 25	18
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2044
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] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2033
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Mar. 31, 2026
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.70%
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	9.70%
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]
Number of Municipal Customers | Customer	10
Increase (Decrease) in Regulatory Assets and Liabilities	$ (27)	2	$ (2)
Kentucky Utilities Co [Member] | Accounting Standards Update 2017-07 [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Liabilities	$ 6
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	$ 20	15
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Dec. 31, 2042
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] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date	Mar. 31, 2026
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	9.70%
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	Sep. 28, 2018	Mar. 14, 2018	Jan. 10, 2018	Dec. 31, 2018	Jun. 14, 2018
PPL Electric [Member] | Pennsylvania Public Utility Commission [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Gas Franchise (Numeric) [Abstract]
Negative Surcharge					7.05%
PPL Electric [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
LKE [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
MISO Transmission Credits				$ 22
LKE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Approved Additional Amount Of Rate Reduction Due To TCJA Prior To Petition	$ 27
LKE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Decrease In Approved Additional Amount Of Rate Reduction Due To The TCJA	$ 13
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity	10.42%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing	$ 35
Percentage requested increase in base rates with anticipated rate case filing	3.00%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 69
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	79
Approved Additional Amount Of Rate Reduction Due To TCJA Prior To Petition	10
Approved Amount Of Rate Reduction Due To TCJA	74
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing	$ 25
Percentage requested increase in base rates with anticipated rate case filing	7.50%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service			$ 166
LGE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Decrease In Approved Additional Amount Of Rate Reduction Due To The TCJA	$ 6
LGE [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	49
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	59
Approved Amount Of Rate Reduction Due To TCJA	54
LGE [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	17
Approved Amount Of Rate Reduction Due To TCJA	16
LGE [Member] | Kentucky Public Service Commission [Member] | Existing Rate Mechanism [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	20
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	20
Approved Amount Of Rate Reduction Due To TCJA	$ 20
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity	10.42%
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing	$ 112
Percentage requested increase in base rates with anticipated rate case filing	6.90%
Regulatory Matters - Kentucky Activities - CPCN Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service			155
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 91
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	108
Approved Additional Amount Of Rate Reduction Due To TCJA Prior To Petition	17
Approved Amount Of Rate Reduction Due To TCJA	101
KU [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Decrease In Approved Additional Amount Of Rate Reduction Due To The TCJA	7
KU [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	70
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	87
Approved Amount Of Rate Reduction Due To TCJA	80
KU [Member] | Kentucky Public Service Commission [Member] | Existing Rate Mechanism [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	21
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	21
Approved Amount Of Rate Reduction Due To TCJA	21
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]
Regulatory Matters - Kentucky Activities - Gas Franchise (Numeric) [Abstract]
Negative Surcharge					7.05%
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
LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Approved Additional Amount Of Rate Reduction Due To TCJA Prior To Petition	27
LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Decrease In Approved Additional Amount Of Rate Reduction Due To The TCJA	$ 13
LG And E And KU Energy LLC [Member] | LGE and KU [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
MISO Transmission Credits				22
LG And E And KU Energy LLC [Member] | LGE [Member]
Regulatory Matters - Kentucky Activities - Gas Franchise (Numeric) [Abstract]
Franchise Agreement Term		5 years
Days of Notice to Modify Franchise Fee		60 days
Franchise Fee Cap		3.00%
Franchise Fee If Recovered From Customers		0.00%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity	10.42%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing	$ 35
Percentage requested increase in base rates with anticipated rate case filing	3.00%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 69
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	79
Approved Amount Of Rate Reduction Due To TCJA	74
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing	$ 25
Percentage requested increase in base rates with anticipated rate case filing	7.50%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service			166
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 49
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	59
Approved Amount Of Rate Reduction Due To TCJA	54
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	17
Approved Amount Of Rate Reduction Due To TCJA	16
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Existing Rate Mechanism [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	20
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	20
Approved Amount Of Rate Reduction Due To TCJA	$ 20
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity	10.42%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing	$ 112
Percentage requested increase in base rates with anticipated rate case filing	6.90%
Regulatory Matters - Kentucky Activities - CPCN Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service			155
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 91
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	108
Approved Amount Of Rate Reduction Due To TCJA	101
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	70
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	87
Approved Amount Of Rate Reduction Due To TCJA	80
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Existing Rate Mechanism [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	21
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	21
Approved Amount Of Rate Reduction Due To TCJA	$ 21
Louisville Gas And Electric Co [Member]
Regulatory Matters - Kentucky Activities - Gas Franchise (Numeric) [Abstract]
Franchise Agreement Term		5 years
Days of Notice to Modify Franchise Fee		60 days
Franchise Fee Cap		3.00%
Franchise Fee If Recovered From Customers		0.00%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
MISO Transmission Credits				22
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
Percentage requested increase in base rates with anticipated rate case filing	3.00%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 69
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	79
Approved Additional Amount Of Rate Reduction Due To TCJA Prior To Petition	10
Approved Amount Of Rate Reduction Due To TCJA	74
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
Percentage requested increase in base rates with anticipated rate case filing	7.50%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service			166
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Decrease In Approved Additional Amount Of Rate Reduction Due To The TCJA	$ 6
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	49
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	59
Approved Amount Of Rate Reduction Due To TCJA	54
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Gas Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	17
Approved Amount Of Rate Reduction Due To TCJA	16
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Existing Rate Mechanism [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	20
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	20
Approved Amount Of Rate Reduction Due To TCJA	$ 20
Kentucky Utilities Co [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
MISO Transmission Credits				$ 22
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity	10.42%
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
Percentage requested increase in base rates with anticipated rate case filing	6.90%
Regulatory Matters - Kentucky Activities - CPCN Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service			$ 155
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	$ 91
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	108
Approved Additional Amount Of Rate Reduction Due To TCJA Prior To Petition	17
Approved Amount Of Rate Reduction Due To TCJA	101
Decrease In Approved Additional Amount Of Rate Reduction Due To The TCJA	7
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Bill Credit [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	70
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	87
Approved Amount Of Rate Reduction Due To TCJA	80
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Existing Rate Mechanism [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA Impact On LG&E And KU Rates [Abstract]
Settled upon amount - before final approval	21
Approved Amount Of Rate Reduction Due To TCJA Prior To Petition	21
Approved Amount Of Rate Reduction Due To TCJA	$ 21

Utility Rate Regulation (Other)

Utility Rate Regulation (Other) (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.3	$ 1.3	$ 1.4
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.3	$ 1.3	$ 1.4

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2018GBP (£)	Dec. 31, 2017GBP (£)
U.K. [Member]
Financing Activities [Line Items]
Capacity | £			£ 1,185
Borrowed | £			195	£ 448
Letters of credit and commercial paper issued | £			4	4
Unused capacity	$ 1,300		987
U.K. [Member] | Uncommitted Credit Facilities [Member]
Financing Activities [Line Items]
Capacity | £			130
Borrowed | £			0	0
Letters of credit and commercial paper issued | £			4	4
Unused capacity | £			126
WPD PLC [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity | £			210
Borrowed	$ 200	$ 200	157	148
Letters of credit and commercial paper issued | £			0	£ 0
Unused capacity | £			£ 54
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	3.17%	2.17%	3.17%	2.17%
Borrowed | £			£ 156
WPD South West [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jul. 31, 2021
Capacity | £			245
Borrowed | £			0	£ 0
Letters of credit and commercial paper issued | £			0	0
Unused capacity | £			£ 245
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%
WPD East Midlands [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jul. 31, 2021
Capacity | £			£ 300
Borrowed	$ 48	$ 244	38	180
Letters of credit and commercial paper issued | £			0	£ 0
Unused capacity | £			£ 262
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%	0.89%	1.12%	0.89%
WPD West Midlands [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jul. 31, 2021
Capacity | £			£ 300
Borrowed	$ 162		0	£ 120
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	0.89%		0.89%
PPL Capital Funding [Member] | U.S. [Member]
Financing Activities [Line Items]
Capacity	$ 1,050
Borrowed	0	$ 0
Letters of credit and commercial paper issued	684	$ 248
Unused capacity	$ 366
PPL Capital Funding [Member] | U.S. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023	Jan. 31, 2022
Capacity	$ 950
Borrowed	0	$ 0
Letters of credit and commercial paper issued	669	230
Unused capacity	$ 281
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]
Expiration date	Mar. 31, 2019
Capacity	$ 100
Borrowed	0	0
Letters of credit and commercial paper issued	15	18
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]
Expiration date	Jan. 31, 2023
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	$ 700
Borrowed	200	100
Letters of credit and commercial paper issued	279	199
Unused capacity	$ 221
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0	0
Letters of credit and commercial paper issued	279	199
Unused capacity	$ 221
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
LGE [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200	100
Letters of credit and commercial paper issued	0	$ 0
Unused capacity	$ 0
Interest rate on outstanding borrowing	2.97%	2.06%	2.97%	2.06%
KU [Member]
Financing Activities [Line Items]
Capacity	$ 598
Borrowed	0	$ 0
Letters of credit and commercial paper issued	433	243
Unused capacity	$ 165
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0	0
Letters of credit and commercial paper issued	235	45
Unused capacity	$ 165
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
KU [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0	0
Letters of credit and commercial paper issued	198	198
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
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]
Expiration date	Oct. 31, 2018
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	$ 700
Borrowed	200	100
Letters of credit and commercial paper issued	279	199
Unused capacity	$ 221
LG And E And KU Energy LLC [Member] | LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0	0
Letters of credit and commercial paper issued	279	199
Unused capacity	$ 221
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
LG And E And KU Energy LLC [Member] | LGE [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200	100
Letters of credit and commercial paper issued	0	0
Unused capacity	0
LG And E And KU Energy LLC [Member] | KU [Member]
Financing Activities [Line Items]
Capacity	598
Borrowed	0	0
Letters of credit and commercial paper issued	433	243
Unused capacity	$ 165
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0	0
Letters of credit and commercial paper issued	235	45
Unused capacity	$ 165
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0	0
Letters of credit and commercial paper issued	198	198
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
Louisville Gas And Electric Co [Member]
Financing Activities [Line Items]
Capacity	700
Borrowed	200	100
Letters of credit and commercial paper issued	279	199
Unused capacity	$ 221
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0	0
Letters of credit and commercial paper issued	279	199
Unused capacity	$ 221
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200	100
Letters of credit and commercial paper issued	0	0
Unused capacity	0
Kentucky Utilities Co [Member]
Financing Activities [Line Items]
Capacity	598
Borrowed	0	0
Letters of credit and commercial paper issued	433	243
Unused capacity	$ 165
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0	0
Letters of credit and commercial paper issued	235	45
Unused capacity	$ 165
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Expiration date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0	0
Letters of credit and commercial paper issued	198	$ 198
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%		70.00%
Potential capacity increase	$ 100

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Short-term Debt [Line Items]
Capacity	$ 2,350
Commercial paper issuances	1,183	$ 474
Unused capacity	$ 1,167
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.82%	1.64%
Capacity	$ 1,000
Commercial paper issuances	669	$ 230
Unused capacity	$ 331
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	2.94%	1.83%
Capacity	$ 350
Commercial paper issuances	279	$ 199
Unused capacity	$ 71
KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.94%	1.97%
Capacity	$ 350
Commercial paper issuances	235	$ 45
Unused capacity	$ 115
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	2.94%	1.83%
Capacity	$ 350
Commercial paper issuances	279	$ 199
Unused capacity	$ 71
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.94%	1.97%
Capacity	$ 350
Commercial paper issuances	235	$ 45
Unused capacity	$ 115
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.94%	1.83%
Capacity	$ 350
Commercial paper issuances	279	$ 199
Unused capacity	$ 71
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	2.94%	1.97%
Capacity	$ 350
Commercial paper issuances	235	$ 45
Unused capacity	$ 115

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) £ in Millions, $ in Millions	1 Months Ended						3 Months Ended		12 Months Ended
	Oct. 31, 2018USD ($)	Oct. 31, 2018GBP (£)	Jun. 30, 2018USD ($)	May 31, 2018USD ($)	May 31, 2018GBP (£)	Mar. 31, 2018USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2018GBP (£)	Dec. 31, 2018USD ($)	Dec. 31, 2018GBP (£)	May 31, 2018GBP (£)	Mar. 31, 2018GBP (£)	Dec. 31, 2017USD ($)
Debt Instrument [Line Items]
Principal outstanding									$ 20,694				$ 20,282
Less current portion of Long-term debt									530				348
Long-term Debt									20,069				19,847
Aggregate maturities of long-term debt (Details) [Abstract]
2,019									530
2,020									1,266
2,021									1,248
2,022									1,274
2,023									2,233
Thereafter									14,143
WPD PLC [Member] | Senior Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £		£ 350
Stated interest rate		3.50%
Maturity date (in years)	Dec. 31, 2026	Dec. 31, 2026
Proceeds from Debt, Net of Issuance Costs | £		£ 346
Proceeds from debt, including premium net of debt issuance costs	$ 456
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									$ 407	£ 319
Earliest date the company may redeem the debt in total by series									Dec. 1, 2026
WPD South Wales [Member] | Index-linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £												£ 30
Stated interest rate						0.01%	0.01%					0.01%
Maturity date (in years)							Dec. 31, 2036	Dec. 31, 2036
Proceeds from Debt, Net of Issuance Costs | £								£ 31
Proceeds from debt, including premium net of debt issuance costs							$ 44
WPD West Midlands [Member] | Index-linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £											£ 30
Stated interest rate				0.01%							0.01%
Maturity date (in years)				Dec. 31, 2028	Dec. 31, 2028
Proceeds from Debt, Net of Issuance Costs | £					£ 31
Proceeds from debt, including premium net of debt issuance costs				$ 41
PPL Capital Funding [Member] | Senior Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 250
Stated interest rate			1.90%
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien									$ 9,400				8,500
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
Earliest date the company may redeem the debt in whole or in part									Oct. 31, 2020
Minimum length of time to convert interest rate mode									1 year
PPL Electric [Member] | First Mortgage Bonds [Member] | Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 400
Stated interest rate			4.15%
Maturity date (in years)			Dec. 31, 2048
Proceeds from Debt, Net of Issuance Costs			$ 394
LGE [Member] | Senior Secured Notes [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 28	$ 28
Stated interest rate						2.30%	2.30%					2.30%
Maturity date (in years)						Dec. 31, 2026
Debt Instruments Future Repurchase Date						Sep. 1, 2021
LGE [Member] | Senior Secured Notes [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 35
Stated interest rate				2.55%							2.55%
Maturity date (in years)				Dec. 31, 2027	Dec. 31, 2027
Debt Instruments Future Repurchase Date				May 3, 2021	May 3, 2021
LGE [Member] | Senior Secured Notes [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 35
Stated interest rate				2.55%							2.55%
Maturity date (in years)				Dec. 31, 2027	Dec. 31, 2027
Debt Instruments Future Repurchase Date				May 3, 2021	May 3, 2021
LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien									$ 5,100				4,700
LGE [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode									1 year
LKE [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate amount of tax-exempt revenue bonds in a term rate mode									$ 505
Aggregate amount of tax-exempt revenue bonds in a variable rate mode									375
KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien									$ 6,300				6,000
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
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									$ 33	£ 26
U.S. [Member]
Debt Instrument [Line Items]
Principal outstanding									$ 13,160				12,919
U.S. [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									3.88%	3.88%
Maturity date of long-term debt range start									Dec. 31, 2020
Maturity date of long-term date range end									Dec. 31, 2047
Principal outstanding									$ 4,325				4,575
U.S. [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									3.99%	3.99%
Maturity date of long-term debt range start									Dec. 31, 2019
Maturity date of long-term date range end									Dec. 31, 2048
Principal outstanding									$ 7,705				7,314
U.S. [Member] | Junior Subordinated Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									5.68%	5.68%
Maturity date of long-term debt range start									Dec. 31, 2067
Maturity date of long-term date range end									Dec. 31, 2073
Principal outstanding									$ 930				930
U.S. [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									2.97%	2.97%
Maturity date of long-term date range end									Dec. 31, 2019
Principal outstanding									$ 200				100
U.K. [Member]
Debt Instrument [Line Items]
Principal outstanding									7,534				7,363
Fair market value adjustments									16				21
Unamortized premium and (discount), net									9				14
Unamortized debt issuance costs									(120)				(122)
Total Long-term Debt									20,599				20,195
Less current portion of Long-term debt									530				348
Long-term Debt									20,069				19,847
Long-term Debt (Numeric) [Abstract]
Principal amount that may be put back to the issuer									$ 6,700	£ 5,300
U.K. [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									5.13%	5.13%
Maturity date of long-term debt range start									Dec. 31, 2020
Maturity date of long-term date range end									Dec. 31, 2040
Principal outstanding									$ 6,471				6,351
Long-term Debt (Numeric) [Abstract]
Principal amount that may be redeemed in total but not in part									$ 287	£ 225
Earliest date the company may redeem the debt in total but not in part									Dec. 21, 2026
U.K. [Member] | Index-linked Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									1.45%	1.45%
Maturity date of long-term debt range start									Dec. 31, 2026
Maturity date of long-term date range end									Dec. 31, 2056
Principal outstanding									$ 1,063				1,012
PPL Electric Utilities Corp [Member]
Debt Instrument [Line Items]
Principal outstanding									3,739				3,339
Unamortized discount									(18)				(16)
Unamortized debt issuance costs									(27)				(25)
Total Long-term Debt									3,694				3,298
Less current portion of Long-term debt									0				0
Long-term Debt									3,694				3,298
Aggregate maturities of long-term debt (Details) [Abstract]
2,019									0
2,020									100
2,021									400
2,022									474
2,023									90
Thereafter									$ 2,675
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									4.22%	4.22%
Maturity date of long-term debt range start									Dec. 31, 2020
Maturity date of long-term date range end									Dec. 31, 2048
Principal outstanding									$ 3,739				3,339
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									9,400				8,500
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
Earliest date the company may redeem the debt in whole or in part									Oct. 31, 2020
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			4.15%
Maturity date (in years)			Dec. 31, 2048
Proceeds from Debt, Net of Issuance Costs			$ 394
LG And E And KU Energy LLC [Member]
Debt Instrument [Line Items]
Principal outstanding									$ 5,541				5,200
Unamortized discount									(13)				(14)
Unamortized debt issuance costs									(26)				(27)
Total Long-term Debt									5,502				5,159
Less current portion of Long-term debt									530				98
Long-term Debt									4,972				5,061
Aggregate maturities of long-term debt (Details) [Abstract]
2,019									530
2,020									975
2,021									348
2,022									0
2,023									13
Thereafter									$ 3,675
LG And E And KU Energy LLC [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									3.97%	3.97%
Maturity date of long-term debt range start									Dec. 31, 2020
Maturity date of long-term date range end									Dec. 31, 2021
Principal outstanding									$ 725				725
LG And E And KU Energy LLC [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									2.97%	2.97%
Maturity date of long-term date range end									Dec. 31, 2019
Principal outstanding									$ 200				100
LG And E And KU Energy LLC [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									3.76%	3.76%
Maturity date of long-term debt range start									Dec. 31, 2019
Maturity date of long-term date range end									Dec. 31, 2045
Principal outstanding									$ 3,966				3,975
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									505
Aggregate amount of tax-exempt revenue bonds in a variable rate mode									$ 375
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				400
LG And E And KU Energy LLC [Member] | Note Payable [Member]
Debt Instrument [Line Items]
Maturity date of long-term debt range start									Dec. 31, 2026
Maturity date of long-term date range end									Dec. 31, 2028
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Secured Notes [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 28	$ 28
Stated interest rate						2.30%	2.30%					2.30%
Maturity date (in years)						Dec. 31, 2026
Debt Instruments Future Repurchase Date						Sep. 1, 2021
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Secured Notes [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 35
Stated interest rate				2.55%							2.55%
Maturity date (in years)				Dec. 31, 2027	Dec. 31, 2027
Debt Instruments Future Repurchase Date				May 3, 2021	May 3, 2021
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Secured Notes [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 35
Stated interest rate				2.55%							2.55%
Maturity date (in years)				Dec. 31, 2027	Dec. 31, 2027
Debt Instruments Future Repurchase Date				May 3, 2021	May 3, 2021
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									$ 5,100				4,700
LG And E And KU Energy LLC [Member] | LGE [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode									1 year
LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien									$ 6,300				6,000
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] | Affiliated Entity [Member] | Note Payable [Member]
Debt Instrument [Line Items]
Notes Payable, Noncurrent				$ 250
Long-term Debt (Numeric) [Abstract]
Stated interest rate				4.00%							4.00%
Maturity date (in years)				May 31, 2028	May 31, 2028
Louisville Gas And Electric Co [Member]
Debt Instrument [Line Items]
Principal outstanding									$ 1,824				1,724
Unamortized discount									(4)				(4)
Unamortized debt issuance costs									(11)				(11)
Total Long-term Debt									1,809				1,709
Less current portion of Long-term debt									434				98
Long-term Debt									1,375				1,611
Aggregate maturities of long-term debt (Details) [Abstract]
2,019									434
2,020									0
2,021									98
2,022									0
2,023									0
Thereafter									$ 1,292
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									2.97%	2.97%
Maturity date of long-term date range end									Dec. 31, 2019
Principal outstanding									$ 200				100
Louisville Gas And Electric Co [Member] | Senior Secured Notes [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 28	$ 28
Stated interest rate						2.30%	2.30%					2.30%
Maturity date (in years)						Dec. 31, 2026
Debt Instruments Future Repurchase Date						Sep. 1, 2021
Louisville Gas And Electric Co [Member] | Senior Secured Notes [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 35
Stated interest rate				2.55%							2.55%
Maturity date (in years)				Dec. 31, 2027	Dec. 31, 2027
Debt Instruments Future Repurchase Date				May 3, 2021	May 3, 2021
Louisville Gas And Electric Co [Member] | Senior Secured Notes [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 35
Stated interest rate				2.55%							2.55%
Maturity date (in years)				Dec. 31, 2027	Dec. 31, 2027
Debt Instruments Future Repurchase Date				May 3, 2021	May 3, 2021
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									3.58%	3.58%
Maturity date of long-term debt range start									Dec. 31, 2019
Maturity date of long-term date range end									Dec. 31, 2045
Principal outstanding									$ 1,624				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									$ 5,100				4,700
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									$ 391
Aggregate amount of tax-exempt revenue bonds in a variable rate mode									147
Kentucky Utilities Co [Member]
Debt Instrument [Line Items]
Principal outstanding									2,342				2,351
Unamortized discount									(8)				(9)
Unamortized debt issuance costs									(13)				(14)
Total Long-term Debt									2,321				2,328
Less current portion of Long-term debt									96				0
Long-term Debt									2,225				2,328
Aggregate maturities of long-term debt (Details) [Abstract]
2,019									96
2,020									500
2,021									0
2,022									0
2,023									13
Thereafter									$ 1,733
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate									3.89%	3.89%
Maturity date of long-term debt range start									Dec. 31, 2019
Maturity date of long-term date range end									Dec. 31, 2045
Principal outstanding									$ 2,342				2,351
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									$ 6,300				$ 6,000
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									$ 114
Aggregate amount of tax-exempt revenue bonds in a variable rate mode									$ 228

Financing Activities Financing

Financing Activities Financing Activities- Equity Securities (Details) $ / shares in Units, $ in Millions		1 Months Ended		12 Months Ended
		Sep. 30, 2018USD ($)shares	May 31, 2018counterparties$ / sharesshares	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)shares	Dec. 31, 2016USD ($)shares	Feb. 28, 2018USD ($)
Equity Programs [Line Items]
Issuance of common stock | $				$ 698	$ 453	$ 144
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]			26,925,000	13,667,000	5,874,000
Common Stock [Member] | Forward Sale Agreement [Member]
Equity Programs [Line Items]
Issuance of common stock | $		$ 520
Common stock shares issued		20,000,000
Sale of stock, price per share | $ / shares			$ 26.7057
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
Maximum [Member] | Common Stock [Member] | Forward Sale Agreement [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Settlement Date			Nov. 30, 2019
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				4,200,000
[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 Billions	Feb. 14, 2019	Nov. 30, 2017	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Distributions [Line Items]
Dividend payable date of quarterly common stock dividend		Jan. 2, 2019
Current quarterly common stock dividend (in dollars per share)		$ 0.410	$ 0.41	$ 0.41	$ 0.41	$ 0.41	$ 0.395	$ 0.395	$ 0.395	$ 0.395	$ 1.64	$ 1.58	$ 1.52
Annualized current quarterly common stock dividend (in dollars per share)		$ 1.64
Subsequent Event [Member]
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)	$ 0.4125
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.65
LKE [Member]
Distributions [Line Items]
Restricted net assets at end of period			$ 2.8								$ 2.8
Unrestricted assets at the end of period			3.3								$ 3.3
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			2.8								$ 2.8
Unrestricted assets at the end of period			3.3								$ 3.3
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			1.2								$ 1.2
Unrestricted assets at the end of period			1.5								$ 1.5
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			1.6								$ 1.6
Unrestricted assets at the end of period			$ 1.8								$ 1.8
Minimum adjusted equity to total capitalization in order to pay dividends											30.00%

Leases (Details)

Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Leases, Rent Expense, Net [Abstract]
Operating Leases, Rent Expense	$ 45	$ 45	$ 50
Operating leases, future minimum rental payments due
2,019	26
2,020	21
2,021	15
2,022	13
2,023	8
Thereafter	33
Total	116
LG And E And KU Energy LLC [Member]
Operating Leases, Rent Expense, Net [Abstract]
Operating Leases, Rent Expense	29	26	26
Operating leases, future minimum rental payments due
2,019	20
2,020	15
2,021	11
2,022	7
2,023	6
Thereafter	11
Total	70
Louisville Gas And Electric Co [Member]
Operating Leases, Rent Expense, Net [Abstract]
Operating Leases, Rent Expense	16	15	15
Operating leases, future minimum rental payments due
2,019	10
2,020	6
2,021	4
2,022	3
2,023	3
Thereafter	4
Total	30
Kentucky Utilities Co [Member]
Operating Leases, Rent Expense, Net [Abstract]
Operating Leases, Rent Expense	12	$ 11	$ 11
Operating leases, future minimum rental payments due
2,019	10
2,020	9
2,021	7
2,022	4
2,023	3
Thereafter	6
Total	$ 39

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)	12 Months Ended
	Dec. 31, 2018USD ($)Integer$ / sharesshares	Dec. 31, 2017USD ($)$ / sharesshares	Dec. 31, 2016USD ($)$ / 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)	1,291,649
Granted (in shares)	369,308
Vested (in shares)	(529,263)
Forfeited (in shares)	(33,491)
Nonvested, end of period (in shares)	1,098,203	1,291,649
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	$ 34.07
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.58	$ 35.30	$ 33.84
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	32.97
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	33.30
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 33.45	$ 34.07
Total fair value of units vested during the period | $	$ 16,000,000	$ 20,000,000	$ 30,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years	3 years	3 years
All Plans [Member] | Restricted Shares And Units [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Vested (in shares)	(45,298)
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)	978,231
Granted (in shares)	263,593
Vested (in shares)	(89,015)
Forfeited (in shares)	(312,685)
Nonvested, end of period (in shares)	840,124	978,231
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 36.67
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	38.26	$ 38.38	$ 35.74
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.78
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	35.26
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.89	$ 36.67
Total fair value of units vested during the period | $	$ 3,000,000	$ 8,000,000	$ 12,000,000
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	17.60%	17.40%	19.60%
All Plans [Member] | Total Shareowner Return Performance Units [Member] | Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	1 year	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)	96,928
Granted (in shares)	234,664
Forfeited (in shares)	(2,634)
Nonvested, end of period (in shares)	328,958	96,928
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	$ 34.42
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	32.21	$ 32.42
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	32.96
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.86	$ 34.42
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)	3,762,183
Exercised (in shares)	(151,750)
Forfeited (in shares)	(695,908)
Outstanding at end of period (in shares)	2,914,525	3,762,183
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	$ 29.42
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares	28.43
Weighted average exercise price per share, forfeited (in dollars per share) | $ / shares	42.87
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares	$ 26.26	$ 29.42
Weighted average remaining contractual term (in years)	3 years 4 months 24 days
Aggregate total intrinsic value | $	$ 6,000,000
Cash received from exercise of stock options | $	5,000,000	$ 19,000,000	$ 52,000,000
Total intrinsic value of stock options exercised | $		8,000,000	18,000,000
All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	25,000,000	32,000,000	27,000,000
Income tax benefit | $	10,000,000	$ 13,000,000	$ 12,000,000
Unrecognized compensation expense | $	$ 10,000,000
Weighted-average period for recognition | Integer	1.6
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)	184,416
Transfer between registrants	(2,906)
Granted (in shares)	76,051
Vested (in shares)	(56,352)
Forfeited (in shares)	(13,872)
Nonvested, end of period (in shares)	187,337	184,416
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	$ 34.20
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	33.95
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30	$ 35.45	$ 34.32
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	32.39
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	33.50
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 33.09	$ 34.20
Total fair value of units vested during the period | $	$ 2,000,000	$ 3,000,000	$ 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)	75,513
Granted (in shares)	22,394
Vested (in shares)	(5,817)
Forfeited (in shares)	(24,227)
Nonvested, end of period (in shares)	67,863	75,513
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
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	38.37	$ 38.37	$ 35.68
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	35.34
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	36.27
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.86	$ 37
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)	8,696
Granted (in shares)	19,899
Forfeited (in shares)	(2,635)
Nonvested, end of period (in shares)	25,960	8,696
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	$ 34.41
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	32.32	$ 34.41
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	32.96
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.96	$ 34.41
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	17.60%	17.40%	19.60%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
PPL Electric Utilities Corp [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	$ 10,000,000	$ 18,000,000	$ 16,000,000
Income tax benefit | $	3,000,000	$ 8,000,000	$ 7,000,000
Unrecognized compensation expense | $	$ 2,000,000
Weighted-average period for recognition | Integer	1.7
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)	231,557
Transfer between registrants	(1,284)
Granted (in shares)	58,377
Vested (in shares)	(154,606)
Forfeited (in shares)	(1,014)
Nonvested, end of period (in shares)	133,030	231,557
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	$ 34.01
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	33.98
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.98	$ 35.25	$ 33.73
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	33.38
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	29.52
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 33.45	$ 34.01
Total fair value of units vested during the period | $	$ 5,000,000	$ 4,000,000	$ 5,000,000
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)	180,289
Granted (in shares)	53,961
Vested (in shares)	(14,547)
Forfeited (in shares)	(70,707)
Nonvested, end of period (in shares)	148,996	180,289
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 36.69
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	38.32	$ 38.24	$ 35.28
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	35.04
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	35.91
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.81	$ 36.69
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)	20,539
Granted (in shares)	49,081
Nonvested, end of period (in shares)	69,620	20,539
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	$ 34.29
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	32.28	$ 34.29
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.87	$ 34.29
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	17.60%	17.40%	19.60%
LG And E And KU Energy LLC [Member] | All Plans [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
LG And E And KU Energy LLC [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	$ 8,000,000	$ 8,000,000	$ 7,000,000
Income tax benefit | $	2,000,000	$ 3,000,000	$ 3,000,000
Unrecognized compensation expense | $	$ 1,000,000
Weighted-average period for recognition | Integer	1.4
LG And E And KU Energy LLC [Member] | Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	15,000,000
Annual grant limit options (in shares)	2,000,000
Annual grant limit for individual participants - performance based awards (in shares)	750,000
Annual grant limit for individual participants - performance based awards | $	$ 15,000,000
LG And E And KU Energy LLC [Member] | Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%
Annual grant limit options (in shares)	3,000,000

Retirement and Postemployment_3

Retirement and Postemployment Benefits (Net Period Defined Benefit Costs (Credits) and Other Changes in Plan Assets and Benefit Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	$ 62	$ 65	$ 66
Interest cost	156	168	174
Expected return on plan assets	(249)	(231)	(228)
Amortization of:
Prior service cost (credit)	10	10	8
Actuarial (gain) loss	84	69	50
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	63	81	70
Settlements	0	1	3
Termination benefits	0	1	0
Net periodic defined benefit costs (credits)	63	83	73
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	(1)	(3)
Net (gain) loss	157	27	253
Prior service costs (credit)	1	(1)	15
Amortization of: [Abstract]
Prior service (cost) credit	(10)	(10)	(8)
Actuarial gain (loss)	(84)	(69)	(50)
Total recognized in OCI and regulatory assets/liabilities	64	(54)	207
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	127	29	280
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	90	(53)	236
Regulatory assets/liabilities	(26)	(1)	(29)
Total recognized in OCI and regulatory assets/liabilities	64	(54)	207
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	40	59	53
Pension Plan [Member] | U.K. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	82	76	69
Interest cost	185	178	235
Expected return on plan assets	(587)	(514)	(504)
Amortization of:
Prior service cost (credit)	0	0	0
Actuarial (gain) loss	151	144	138
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(169)	(116)	(62)
Settlements	0	0	0
Termination benefits	0	0	0
Net periodic defined benefit costs (credits)	(169)	(116)	(62)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	201	346	7
Prior service costs (credit)	13	0	0
Amortization of: [Abstract]
Prior service (cost) credit	0	0	0
Actuarial gain (loss)	(151)	(144)	(138)
Total recognized in OCI and regulatory assets/liabilities	63	202	(131)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(106)	86	(193)
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	63	202	(131)
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	(226)	(151)	(95)
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	7	7	7
Interest cost	21	23	26
Expected return on plan assets	(23)	(22)	(22)
Amortization of:
Prior service cost (credit)	(1)	(1)	0
Actuarial (gain) loss	0	1	1
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	4	8	12
Settlements	0	0	0
Termination benefits	0	0	0
Net periodic defined benefit costs (credits)	4	8	12
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	8	(28)	9
Prior service costs (credit)	0	8	0
Amortization of: [Abstract]
Prior service (cost) credit	1	1	(1)
Actuarial gain (loss)	0	(1)	(1)
Total recognized in OCI and regulatory assets/liabilities	9	(20)	7
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	13	(12)	19
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	20	(25)	7
Regulatory assets/liabilities	(11)	5	0
Total recognized in OCI and regulatory assets/liabilities	9	(20)	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	5	7
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	12	10
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	(1)	0	1
LG And E And KU Energy LLC [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	11	11	6
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	11	11	6
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	25	24	23
Interest cost	63	68	71
Expected return on plan assets	(102)	(92)	(91)
Amortization of:
Prior service cost (credit)	9	8	8
Actuarial (gain) loss	35	31	21
Net periodic defined benefit costs (credits)	$ 30	$ 39	$ 32
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	$ 40	$ 30	$ 119
Prior service costs (credit)	0	7	0
Amortization of: [Abstract]
Prior service (cost) credit	(9)	(8)	(8)
Actuarial gain (loss)	(35)	(32)	(21)
Total recognized in OCI and regulatory assets/liabilities	(4)	(3)	90
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	26	36	122
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(25)	33	42
Regulatory assets/liabilities	21	(36)	48
Total recognized in OCI and regulatory assets/liabilities	(4)	(3)	90
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	$ 21	$ 28	$ 24
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements	$ 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	$ 5
Interest cost	8	9	9
Expected return on plan assets	(9)	(7)	(6)
Amortization of:
Prior service cost (credit)	1	1	3
Actuarial (gain) loss	0	0	(1)
Net periodic defined benefit costs (credits)	$ 4	$ 7	$ 10
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	$ 1	$ (14)	$ 6
Prior service costs (credit)	0	8	0
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	(3)
Actuarial gain (loss)	0	0	1
Total recognized in OCI and regulatory assets/liabilities	0	(7)	4
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	4	0	14
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	4	(2)	2
Regulatory assets/liabilities	(4)	(5)	2
Total recognized in OCI and regulatory assets/liabilities	0	(7)	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	$ 3	$ 5	$ 6
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	$ (3)	$ (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]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	(3)	(4)	(3)
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	(2)	(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	(2)	(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	2	7	5
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	7	5
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	12	13	15
Expected return on plan assets	(22)	(22)	(21)
Amortization of:
Prior service cost (credit)	5	5	4
Actuarial (gain) loss	7	9	7
Net periodic defined benefit costs (credits)	$ 3	$ 6	$ 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	$ (3)	$ (4)	$ (3)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss	22	(9)	22
Prior service costs (credit)	0	7	0
Amortization of: [Abstract]
Prior service (cost) credit	(5)	(5)	(4)
Actuarial gain (loss)	(7)	(9)	(7)
Total recognized in OCI and regulatory assets/liabilities	10	(16)	11
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	13	(10)	17
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	10	(16)	11
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ 4	$ 8	$ 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	$ (3)	$ (4)	$ (3)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements	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	$ 2	$ 5	$ 4
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member]
Amortization of:
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ (3)	$ (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	$ 2	$ 3	$ 3
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ (3)	$ (4)	$ (3)
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	$ 2	$ 3	$ 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	$ (2)	$ (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	$ 2	$ 4	$ 5
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ (2)	$ (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	$ (2)	$ (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	$ 1	$ 2
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ (2)	$ (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, 2018	Dec. 31, 2017	Dec. 31, 2016
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	$ 535	$ 284
Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	4.35%	3.70%
Benefit obligations valuation rate of compensation increase	3.79%	3.78%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost	3.70%	4.21%	4.59%
Net periodic benefit costs discount rate - interest cost	3.70%	4.21%	4.59%
Net periodic benefit costs rate of compensation increase	3.78%	3.95%	3.93%
Net periodic benefit costs expected return on plan assets	7.25%	7.00%	7.00%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	6.60%	6.60%	7.00%
Health care cost trend rate assumed for next year, cost	6.60%	7.00%	6.80%
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	2,023	2,022	2,022
Year that the rate reaches the ultimate trend rate, cost	2,022	2,022	2,020
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 4,288	$ 4,079
Service cost	62	65	$ 66
Interest cost	156	168	174
Participant contributions	0	0
Plan Amendments	1	(1)
Actuarial (gain) loss	(352)	233
Settlements	0	(6)
Termination benefits	0	1
Gross benefits paid	(272)	(251)
Federal subsidy	0	0
Currency conversion	0	0
Benefit Obligation, end of period	3,883	4,288	4,079
Change in Plan Assets [Roll Forward]
Balance at beginning of period	3,488	3,243
Actual return on plan assets	(260)	437
Employer contributions	153	65
Participant contributions	0	0
Transfer out	0	0
Settlements	0	(6)
Gross benefits paid	(272)	(251)
Currency conversion	0	0
Balance at end of period	3,109	3,488	$ 3,243
Funded Status, end of period	(774)	(800)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	0
Current liability	(13)	(13)
Noncurrent liability	(761)	(787)
Net amount recognized, end of period	(774)	(800)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	40	49
Net actuarial (gain) loss	1,207	1,134
Total	1,247	1,183
Total accumulated benefit obligation for defined benefit pension plans	3,668	4,000
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	370	374
Regulatory assets/liabilities	877	809
Total	1,247	1,183
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	3,883	4,288
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	3,109	3,488
Accumulated benefit obligation	3,668	4,000
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 3,109	$ 3,488
Pension Plan [Member] | U.K. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	2.98%	2.65%
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 - service cost	2.73%	2.99%	3.90%
Net periodic benefit costs discount rate - interest cost	2.31%	2.41%	3.14%
Net periodic benefit costs rate of compensation increase	3.50%	3.50%	4.00%
Net periodic benefit costs expected return on plan assets	7.23%	7.22%	7.20%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 8,219	$ 7,383
Service cost	82	76	$ 69
Interest cost	185	178	235
Participant contributions	13	13
Plan Amendments	12	0
Actuarial (gain) loss	(406)	293
Settlements	0	(1)
Termination benefits	0	0
Gross benefits paid	(381)	(345)
Federal subsidy	0	0
Currency conversion	(449)	622
Benefit Obligation, end of period	7,275	8,219	7,383
Change in Plan Assets [Roll Forward]
Balance at beginning of period	8,490	7,211
Actual return on plan assets	(30)	480
Employer contributions	188	486
Participant contributions	13	13
Transfer out	0	0
Settlements	0	(1)
Gross benefits paid	(381)	(345)
Currency conversion	(479)	646
Balance at end of period	7,801	8,490	$ 7,211
Funded Status, end of period	526	271
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	535	284
Current liability	(1)	0
Noncurrent liability	(8)	(13)
Net amount recognized, end of period	526	271
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	12	0
Net actuarial (gain) loss	2,806	2,755
Total	2,818	2,755
Total accumulated benefit obligation for defined benefit pension plans	6,689	7,542
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total	2,818	2,755
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	9	3,083
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	0	3,070
Accumulated benefit obligation	9	10
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	4.31%	3.64%
Benefit obligations valuation rate of compensation increase	3.76%	3.75%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost	3.64%	4.11%	4.48%
Net periodic benefit costs discount rate - interest cost	3.64%	4.11%	4.48%
Net periodic benefit costs rate of compensation increase	3.75%	3.92%	3.91%
Net periodic benefit costs expected return on plan assets	6.40%	6.21%	6.11%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 589	$ 591
Service cost	7	7	$ 7
Interest cost	21	23	26
Participant contributions	13	14
Plan Amendments	0	8
Actuarial (gain) loss	(34)	4
Settlements	0	0
Termination benefits	0	0
Gross benefits paid	(58)	(59)
Federal subsidy	0	1
Currency conversion	0	0
Benefit Obligation, end of period	538	589	591
Change in Plan Assets [Roll Forward]
Balance at beginning of period	405	378
Actual return on plan assets	(20)	54
Employer contributions	23	15
Participant contributions	11	13
Transfer out	(65)	0
Settlements	0	0
Gross benefits paid	(53)	(55)
Currency conversion	0	0
Balance at end of period	301	405	$ 378
Funded Status, end of period	(237)	(184)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	2	2
Current liability	(3)	(3)
Noncurrent liability	(236)	(183)
Net amount recognized, end of period	(237)	(184)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	10	9
Net actuarial (gain) loss	24	16
Total	34	25
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	21	15
Regulatory assets/liabilities	13	10
Total	34	25
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	285	246
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	$ 120	$ 62
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	4.35%	3.69%
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	3.69%	4.19%	4.56%
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%	7.00%	7.00%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	6.60%	6.60%	7.00%
Health care cost trend rate assumed for next year, cost	6.60%	7.00%	6.80%
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	2,023	2,022	2,022
Year that the rate reaches the ultimate trend rate, cost	2,022	2,022	2,020
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 1,771	$ 1,669
Service cost	25	24	$ 23
Interest cost	63	68	71
Participant contributions	0	0
Plan Amendments	0	6
Actuarial (gain) loss	(168)	113
Gross benefits paid	(111)	(109)
Benefit Obligation, end of period	1,580	1,771	1,669
Defined Benefit Plan One Time Cash Payouts To Terminated Vested Employees	52	50
Change in Plan Assets [Roll Forward]
Balance at beginning of period	1,402	1,315
Actual return on plan assets	(106)	175
Employer contributions	109	21
Participant contributions	0	0
Gross benefits paid	(111)	(109)
Balance at end of period	1,294	1,402	$ 1,315
Funded Status, end of period	(286)	(369)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	0
Current liability	(4)	(4)
Noncurrent liability	(282)	(365)
Net amount recognized, end of period	(286)	(369)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	35	44
Net actuarial (gain) loss	439	434
Total	474	478
Total accumulated benefit obligation for defined benefit pension plans	1,467	1,616
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	118	144
Regulatory assets/liabilities	356	334
Total	474	478
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	1,580	1,771
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	1,294	1,402
Accumulated benefit obligation	1,467	1,616
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 1,294	$ 1,402
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	4.32%	3.65%
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	3.65%	4.12%	4.49%
Net periodic benefit costs rate of compensation increase	3.50%	3.50%	3.50%
Net periodic benefit costs expected return on plan assets	7.15%	6.82%	6.82%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 223	$ 220
Service cost	4	4	$ 5
Interest cost	8	9	9
Participant contributions	8	8
Plan Amendments	0	8
Actuarial (gain) loss	(16)	(7)
Gross benefits paid	(22)	(19)
Benefit Obligation, end of period	205	223	220
Change in Plan Assets [Roll Forward]
Balance at beginning of period	116	98
Actual return on plan assets	(9)	14
Employer contributions	24	15
Participant contributions	8	8
Gross benefits paid	(22)	(19)
Balance at end of period	117	116	$ 98
Funded Status, end of period	(88)	(107)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	2	2
Current liability	(3)	(3)
Noncurrent liability	(87)	(106)
Net amount recognized, end of period	(88)	(107)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	12	13
Net actuarial (gain) loss	(25)	(26)
Total	(13)	(13)
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	10	6
Regulatory assets/liabilities	(23)	(19)
Total	$ (13)	$ (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	4.33%	3.65%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	3.65%	4.13%	4.49%
Net periodic benefit costs expected return on plan assets	7.25%	7.00%	7.00%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 326	$ 329
Service cost	1	1	$ 1
Interest cost	12	13	15
Plan Amendments	0	6
Actuarial (gain) loss	(24)	11
Gross benefits paid	(30)	(34)
Benefit Obligation, end of period	285	326	329
Defined Benefit Plan One Time Cash Payouts To Terminated Vested Employees	16	19
Change in Plan Assets [Roll Forward]
Balance at beginning of period	325	318
Actual return on plan assets	(24)	41
Employer contributions	10	0
Gross benefits paid	(30)	(34)
Balance at end of period	281	325	$ 318
Funded Status, end of period	(4)	(1)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent liability	(4)	(1)
Net amount recognized, end of period	(4)	(1)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	22	27
Net actuarial (gain) loss	(107)	92
Total	129	119
Total accumulated benefit obligation for defined benefit pension plans	285	326
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total	129	119
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	44
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	65	74
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	1	36
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	$ 25	$ 32

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, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2017
Pension Plan [Member] | U.S. [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,109	$ 3,488	$ 3,243	$ 3,109	$ 3,488
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,109	3,488	3,243
Balance at end of period		3,109	3,488
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 153	65
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				13
Estimated Future Benefit Payments (Details) [Abstract]
2,019				274
2,020				266
2,021				265
2,022				265
2,023				264
2024-2028				1,290
Pension Plan [Member] | U.S. [Member] | Subsequent Event [Member]
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	50
Pension Plan [Member] | U.S. [Member] | Master Trust [Member]
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				$ 71
Number Of Days Notice Required To Redeem Shares		45 days
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	3,109	$ 3,488	3,488	$ 3,109	$ 3,488
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,109	3,488
Balance at end of period		3,109	3,488
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	591	716	716	591	716
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	591	716
Balance at end of period		591	716
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	924	931	931	924	931
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	924	931
Balance at end of period		924	931
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	46	37	40	46	37
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	46	37	40
Actual return on plan assets relating to assets still held at the reporting date		(1)	1
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		7	(4)
Balance at end of period		46	37
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				220	301
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				220	301
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				340	364
Measured at fair value not using net asset value per share				159	229
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				159	229
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				466	538
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				543	611
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				212	186
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				212	186
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				0	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				899	883
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				874	870
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				25	13
Fair value at end of period	25	13	13	25	13
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	25	13	13
Actual return on plan assets relating to assets still held at the reporting date		(2)	0
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		11	0
Balance at end of period		25	13
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				17	10
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				17	10
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				90	109
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	3,240	3,561	3,561	3,240	3,561
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,240	3,561
Balance at end of period		3,240	3,561
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				65	80
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				175	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				33	51
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				33	51
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				21	24
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				21	24
Fair value at end of period	21	24	27	21	24
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	21	24	27
Actual return on plan assets relating to assets still held at the reporting date		1	1
Actual return on plan assets relating to assets sold during the period		0
Purchases, sales and settlements		(4)	(4)
Balance at end of period		21	24
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	(2)	72	72	(2)	72
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(2)	72
Balance at end of period		(2)	72
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	(129)	(145)	(145)	$ (129)	$ (145)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(129)	(145)
Balance at end of period		(129)	(145)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				55.00%	56.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				55.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				30.00%	32.00%
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				15.00%	14.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				10.00%	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				43.00%	43.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				43.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				39.00%	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				4.00%	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				2.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				2.00%
Pension Plan [Member] | U.K. [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				100.00%	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	7,801	8,490	7,211	$ 7,801	$ 8,490
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	7,801	8,490	7,211
Balance at end of period		7,801	8,490
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 188	486
Amount to be contributed to plan in the next fiscal year				277
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]
2,019				337
2,020				340
2,021				344
2,022				349
2,023				352
2024-2028				1,781
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	147	$ 216	216	147	216
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	147	216
Balance at end of period		147	216
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	2,937	3,140	3,140	2,937	3,140
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	2,937	3,140
Balance at end of period		2,937	3,140
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				$ 147	$ 216
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				147	216
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%	2.00%
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				$ 27	$ 157
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				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				$ 76	$ 98
Pension Plan [Member] | U.K. [Member] | Asian Pacific 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				$ 49	$ 60
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				$ 105	$ 123
Pension Plan [Member] | U.K. [Member] | Emerging Markets 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				$ 44	$ 62
Pension Plan [Member] | U.K. [Member] | Global Equities Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				19.00%	16.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				10.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share				$ 1,465	$ 1,335
Pension Plan [Member] | U.K. [Member] | Global Tactical Asset Allocation Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				31.00%	33.00%
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				$ 2,437	$ 2,807
Pension Plan [Member] | U.K. [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				38.00%	37.00%
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				$ 4	$ 3
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				4	3
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				2,933	3,137
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				2,933	3,137
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				5.00%
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				$ 485	$ 492
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	7,772	8,490	8,490	7,772	8,490
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	7,772	8,490
Balance at end of period		7,772	8,490
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	29	0	0	$ 29	$ 0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	29	0
Balance at end of period		29	0
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	301	405	378	$ 301	$ 405
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	301	405	378
Balance at end of period		301	405
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		23	15
Amount to be contributed to plan in the next fiscal year				15
Estimated Future Benefit Payments (Details) [Abstract]
2,019				50
2,020				50
2,021				49
2,022				48
2,023				46
2024-2028				210
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2019				0
Federal subsidy 2020				1
Federal subsidy 2021				0
Federal subsidy 2022				1
Federal subsidy 2023				0
Federal subsidy 2024-2028				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	10	10	6	10
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	6	10
Balance at end of period		6	10
Other Postretirement Benefits Plan [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	28	30	30	28	30
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	28	30
Balance at end of period		28	30
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				4.00%	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]
Fair value at end of period	6	$ 10	10	$ 6	$ 10
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	6	10
Balance at end of period		6	10
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	10
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				40.00%	47.00%
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				$ 69	$ 123
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	$ 96
Other Postretirement Benefits Plan [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				56.00%	49.00%
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]
Fair value at end of period	28	30	30	$ 28	$ 30
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	28	30
Balance at end of period		28	30
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				28	30
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	171	259	259	171	259
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	171	259
Balance at end of period		171	259
Other Postretirement Benefits Plan [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	1	1	1	1	1
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1	1
Balance at end of period		1	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	129	145	145	129	145
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	129	145
Balance at end of period		129	145
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	1,294	1,402	1,315	1,294	1,402
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,294	1,402	1,315
Balance at end of period		1,294	1,402
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 109	$ 21
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				4
Estimated Future Benefit Payments (Details) [Abstract]
2,019				112
2,020				112
2,021				113
2,022				113
2,023				112
2024-2028				547
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	20
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member]
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary				1,300	$ 1,400
Undivided interest percentage in each asset category that PPL subsidiary holds		42.00%	40.00%
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				$ 71
Number Of Days Notice Required To Redeem Shares		45 days
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	3,240	$ 3,561	$ 3,561	$ 3,240	$ 3,561
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,240	3,561
Balance at end of period		3,240	3,561
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	591	716	716	591	716
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	591	716
Balance at end of period		591	716
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	924	931	931	924	931
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	924	931
Balance at end of period		924	931
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	46	37	40	46	37
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	46	37	40
Actual return on plan assets relating to assets still held at the reporting date		(1)	1
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		7	(4)
Balance at end of period		46	37
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				220	301
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				220	301
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				340	364
Measured at fair value not using net asset value per share				159	229
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				159	229
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				466	538
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				543	611
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				212	186
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				212	186
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				0	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				899	883
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				874	870
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				25	13
Fair value at end of period	25	13	13	25	13
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	25	13	13
Actual return on plan assets relating to assets still held at the reporting date		(2)	0
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		11	0
Balance at end of period		25	13
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				17	10
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				17	10
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				90	109
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	3,109	3,488	3,488	3,109	3,488
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,109	3,488
Balance at end of period		3,109	3,488
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				65	80
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				175	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				33	51
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				33	51
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				21	24
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				21	24
Fair value at end of period	21	24	27	21	24
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	21	24	27
Actual return on plan assets relating to assets still held at the reporting date		1	1
Actual return on plan assets relating to assets sold during the period		0
Purchases, sales and settlements		(4)	(4)
Balance at end of period		21	24
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	(2)	72	72	(2)	72
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(2)	72
Balance at end of period		(2)	72
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	(129)	(145)	(145)	$ (129)	$ (145)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(129)	(145)
Balance at end of period		(129)	(145)
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				55.00%	56.00%
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				30.00%	32.00%
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				15.00%	14.00%
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				10.00%	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				43.00%	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				39.00%	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				4.00%	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				2.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation				2.00%
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	117	116	98	$ 117	$ 116
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	117	116	98
Balance at end of period		117	116
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		24	15
Amount to be contributed to plan in the next fiscal year				15
Estimated Future Benefit Payments (Details) [Abstract]
2,019				15
2,020				15
2,021				16
2,022				16
2,023				16
2024-2028				78
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2019				0
Federal subsidy 2020				0
Federal subsidy 2021				0
Federal subsidy 2022				1
Federal subsidy 2023				0
Federal subsidy 2024-2028				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	281	325	318	281	325
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	281	325	318
Balance at end of period		281	325
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		$ 10	$ 0
Amount to be contributed to plan in the next fiscal year				0
Estimated Future Benefit Payments (Details) [Abstract]
2,019				25
2,020				25
2,021				24
2,022				23
2,023				22
2024-2028				95
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Subsequent Event [Member]
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	1
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member]
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary				281	$ 325
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				$ 71
Number Of Days Notice Required To Redeem Shares		45 days
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	3,240	$ 3,561	$ 3,561	$ 3,240	$ 3,561
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,240	3,561
Balance at end of period		3,240	3,561
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	591	716	716	591	716
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	591	716
Balance at end of period		591	716
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	924	931	931	924	931
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	924	931
Balance at end of period		924	931
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	46	37	40	46	37
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	46	37	40
Actual return on plan assets relating to assets still held at the reporting date		(1)	1
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		7	(4)
Balance at end of period		46	37
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				220	301
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				220	301
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				340	364
Measured at fair value not using net asset value per share				159	229
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				159	229
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				466	538
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				543	611
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				212	186
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				212	186
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				0	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				899	883
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				874	870
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				25	13
Fair value at end of period	25	13	13	25	13
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	25	13	13
Actual return on plan assets relating to assets still held at the reporting date		(2)	0
Actual return on plan assets relating to assets sold during the period		3
Purchases, sales and settlements		11	0
Balance at end of period		25	13
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				17	10
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				17	10
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				90	109
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	3,109	3,488	3,488	3,109	3,488
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,109	3,488
Balance at end of period		3,109	3,488
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				65	80
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				175	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				33	51
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				33	51
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				21	24
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				21	24
Fair value at end of period	21	24	27	21	24
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	21	24	27
Actual return on plan assets relating to assets still held at the reporting date		1	1
Actual return on plan assets relating to assets sold during the period		0
Purchases, sales and settlements		(4)	(4)
Balance at end of period		21	24
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	(2)	72	72	(2)	72
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(2)	72
Balance at end of period		(2)	72
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	(129)	(145)	(145)	$ (129)	$ (145)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	$ (129)	(145)
Balance at end of period		$ (129)	$ (145)
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				55.00%	56.00%
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				30.00%	32.00%
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				15.00%	14.00%
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				10.00%	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				43.00%	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				39.00%	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				4.00%	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				2.00%	1.00%
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, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 40	$ 36	$ 35
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	20	18	17
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	6	5	5
Kentucky Utilities Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 5	$ 4	$ 4

Jointly Owned Facilities (Detai

Jointly Owned Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 427	$ 427
Accumulated depreciation	77	69
Construction work in progress	$ 0	$ 1
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,063	$ 1,032
Accumulated depreciation	199	176
Construction work in progress	$ 293	$ 198
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	$ 427	$ 427
Accumulated depreciation	77	69
Construction work in progress	$ 0	$ 1
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	$ 1,063	$ 1,032
Accumulated depreciation	199	176
Construction work in progress	$ 293	$ 198
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	$ 41	$ 41
Accumulated depreciation	20	17
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	53.00%	53.00%
Electric plant	$ 51	$ 52
Accumulated depreciation	17	15
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	$ 427	$ 427
Accumulated depreciation	77	69
Construction work in progress	$ 0	$ 1
Louisville Gas And Electric Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	14.25%	14.25%
Electric plant	$ 226	$ 215
Accumulated depreciation	39	36
Construction work in progress	$ 152	$ 102
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	11	9
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	$ 77	$ 73
Accumulated depreciation	24	21
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	$ 120
Accumulated depreciation	9	8
Construction work in progress	$ 0	$ 1
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	1	1
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	62.00%	62.00%
Electric plant	$ 66	$ 66
Accumulated depreciation	31	27
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	15	13
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	$ 837	$ 817
Accumulated depreciation	160	140
Construction work in progress	$ 141	$ 96
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	25	20
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	$ 129	$ 120
Accumulated depreciation	41	34
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	$ 428	$ 431
Accumulated depreciation	36	31
Construction work in progress	$ 0	$ 4
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	1
Construction work in progress	$ 0	$ 0

Commitments and Contingencies_2

Commitments and Contingencies (Energy Purchases, Energy Sales, Other Commitments and Legal Matters) (Details) $ in Millions	Nov. 30, 2018USD ($)	Oct. 29, 2018USD ($)	Dec. 31, 2018USD ($)residentclaimmi	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015coal-fired_unit
Claim By Former Affiliate [Abstract]
Restructuring And Related Activities Ownership Percentage By Riverstone		35.00%
Amount Of Alleged Improper Distribution		$ 733
Amount of special cash dividend	$ 500
LKE [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Expiration date of the power purchase agreement with OVEC			Jun. 30, 2040
LKE [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2,019			$ 27
2,020			26
2,021			27
2,022			27
2,023			27
Thereafter			430
Total future obligation			564
Purchases			$ 20	$ 20	$ 23
LGE [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident			6
Number of miles within plant that would include a class of residents | mi			4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim			1
Generating units retired at the Cane Run plant | coal-fired_unit						3
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
LGE and KU [Member] | Natural Gas Fuel Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
LGE and KU [Member] | Natural Gas Retail Supply Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
LGE and KU [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,023
LGE and KU [Member] | Coal Transportation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,027
LGE and KU [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026
LG And E And KU Energy LLC [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Expiration date of the power purchase agreement with OVEC			Jun. 30, 2040
LG And E And KU Energy LLC [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2,019			$ 27
2,020			26
2,021			27
2,022			27
2,023			27
Thereafter			430
Total future obligation			564
Purchases			$ 20	20	23
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 miles within plant that would include a class of residents | mi			4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim			1
Generating units retired at the Cane Run plant | coal-fired_unit						3
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
LG And E And KU Energy LLC [Member] | LGE and KU [Member] | Natural Gas Fuel Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
LG And E And KU Energy LLC [Member] | LGE and KU [Member] | Natural Gas Retail Supply Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
LG And E And KU Energy LLC [Member] | LGE and KU [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,023
LG And E And KU Energy LLC [Member] | LGE and KU [Member] | Coal Transportation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,027
LG And E And KU Energy LLC [Member] | LGE and KU [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026
Louisville Gas And Electric Co [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Expiration date of the power purchase agreement with OVEC			Jun. 30, 2040
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident			6
Number of miles within plant that would include a class of residents | mi			4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim			1
Generating units retired at the Cane Run plant | coal-fired_unit						3
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]
2,019			$ 19
2,020			18
2,021			19
2,022			19
2,023			19
Thereafter			297
Total future obligation			391
Purchases			$ 14	14	16
Louisville Gas And Electric Co [Member] | Natural Gas Fuel Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
Louisville Gas And Electric Co [Member] | Natural Gas Retail Supply Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
Louisville Gas And Electric Co [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,023
Louisville Gas And Electric Co [Member] | Coal Transportation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,027
Louisville Gas And Electric Co [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026
Kentucky Utilities Co [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Expiration date of the power purchase agreement with OVEC			Jun. 30, 2040
Kentucky Utilities Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2,019			$ 8
2,020			8
2,021			8
2,022			8
2,023			8
Thereafter			133
Total future obligation			173
Purchases			$ 6	$ 6	$ 7
Kentucky Utilities Co [Member] | Natural Gas Fuel Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
Kentucky Utilities Co [Member] | Natural Gas Retail Supply Purchase Contracts [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,020
Kentucky Utilities Co [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,023
Kentucky Utilities Co [Member] | Coal Transportation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,027
Kentucky Utilities Co [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Matter and Other) (Details) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2018USD ($)employees	Dec. 31, 2018USD ($)employees	Dec. 31, 2017USD ($)
PPL Electric [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Number Of Employees Displaced | employees	86
Separation Benefits | $	$ 6
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual | $		$ 11	$ 10
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Number Of Employees Displaced | employees	86
Separation Benefits | $	$ 6
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual | $		$ 11	$ 10
LG And E And KU Energy LLC [Member] | KU [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Number Of Union Employees | employees		68
Collective Bargaining Agreement Term		3 years
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Number Of Union Employees | employees		68
Collective Bargaining Agreement Term		3 years

Commitments and Contingencies_4

Commitments and Contingencies (Guarantees and Other Assurances) (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2018	Dec. 31, 2018USD ($)Integer	Dec. 31, 2017USD ($)
Guarantor Obligations [Line Items]
Recorded liability for all guarantees		$ 6	$ 17
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
Expiration date		2,020
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		$ 80
PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure		$ 8
Expiration date	2,020	2,020
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure		$ 200
Expiration date		2,021
Term of guarantee (in years)		12 years
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		$ 8
Expiration date		2,020
LG And E And KU Energy LLC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			$ 11
LG And E And KU Energy LLC [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Expiration date		2,021
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
Expiration date		2,021
Term of guarantee (in years)		12 years
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues		$ 200
LG And E And KU Energy LLC [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt		113
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		78
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		$ 35
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		$ 113

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	May 31, 2018	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Oct. 31, 2018	Jun. 30, 2018
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Interest Income from Affiliate			$ 8	$ 5	$ 0
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction			59	182	132
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction			148	64	69
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
Intercompany Note Affiliate Maximum Borrowing Capacity Increase							$ 250
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates			113	225
Interest Expense, Related Party			25	18	17
Long-term debt to affiliate			650	400
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction			$ 26	$ 20	18
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing			3.85%	2.87%
Notes payable to affiliates			$ 113	$ 225
Intercompany note with affiliate maximum borrowing capacity			$ 375
Intercompany Note Affiliate Maximum Borrowing Capacity Increase						$ 75
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Debt Instrument, Term			10 years
Intercompany borrowings demand note rate on outstanding borrowing			3.50%
Interest Expense, Related Party			$ 14	14
Long-term debt to affiliate			400	400
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member]
Intercompany Borrowings (Numeric) [Abstract]
Interest Expense, Related Party		$ 7
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member] | Note Payable [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable, Noncurrent	$ 250
Stated interest rate	4.00%
Maturity date (in years)	May 31, 2028
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			151	169	178
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			$ 169	$ 190	$ 194

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Other Income [Line Items]
Economic foreign currency exchange contracts	$ 150	$ (261)	$ 384
Defined benefit plans - non-service credits	257	167	112
Interest income	6	2	3
Allowance for funds used during construction - equity component	21	16	19
Miscellaneous	6	17	6
Total Other Income	440	(59)	524
Other Expense [Line Items]
Charitable contributions	24	8	9
Miscellaneous	20	21	13
Total Other Expense	44	29	22
Other Income (Expense) - net	396	(88)	502
PPL Electric Utilities Corp [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	5	1	3
Interest income	2	1	1
Allowance for funds used during construction - equity component	20	15	18
Miscellaneous	0	0	2
Total Other Income	27	17	24
Other Expense [Line Items]
Charitable contributions	3	2	2
Miscellaneous	1	3	2
Total Other Expense	4	5	4
Other Income (Expense) - net	$ 23	$ 12	$ 20

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents	$ 621	$ 485
Restricted cash and cash equivalents	22	26
Special use funds	59	0
Price risk management assets:
Foreign currency contracts	202	163
Cross-currency swaps	135	101
Total price risk management assets	337	264
Total Assets	1,039	775
Price risk management liabilities:
Interest rate swaps	20	26
Foreign currency contracts	2	148
Total price risk management liabilities	22	174
Level 1 [Member]
Assets
Cash and cash equivalents	621	485
Restricted cash and cash equivalents	22	26
Special use funds	59	0
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total Assets	702	511
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
Special use funds	0	0
Price risk management assets:
Foreign currency contracts	202	163
Cross-currency swaps	135	101
Total price risk management assets	337	264
Total Assets	337	264
Price risk management liabilities:
Interest rate swaps	20	26
Foreign currency contracts	2	148
Total price risk management liabilities	22	174
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
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	267	49
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total Assets	269	51
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	267	49
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total Assets	269	51
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	24	30
Price risk management assets:
Total Assets	24	30
Price risk management liabilities:
Interest rate swaps	20	26
Total price risk management liabilities	20	26
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	24	30
Price risk management assets:
Total Assets	24	30
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	20	26
Total price risk management liabilities	20	26
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	10	15
Price risk management assets:
Total Assets	10	15
Price risk management liabilities:
Interest rate swaps	20	26
Total price risk management liabilities	20	26
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	10	15
Price risk management assets:
Total Assets	10	15
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	20	26
Total price risk management liabilities	20	26
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	14	15
Price risk management assets:
Total Assets	14	15
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	14	15
Price risk management assets:
Total Assets	14	15
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, 2018	Dec. 31, 2017
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 20,599	$ 20,195
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	22,939	23,783
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	3,694	3,298
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	3,901	3,769
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,502	5,159
LG And E And KU Energy LLC [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,768	5,670
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	1,809	1,709
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	1,874	1,865
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,321	2,328
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 2,451	$ 2,605

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 40	$ 20
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 Billions	1 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2018GBP (£)	Sep. 30, 2016GBP (£)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness			$ 0	$ 0
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 - Cash Flow Hedges (Numeric) [Abstract]
Earliest maturity date of cross-currency cash flow hedge contracts			2,021
Latest maturity date of cross-currency cash flow hedge contracts			2,028
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness			$ 0	0	0
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
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			$ 2,200			£ 1.5
Earliest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity			Jan. 31, 2019
Latest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity			Oct. 30, 2020
Economic Hedges [Member] | Foreign Currency Contracts [Member] | Hedges 2017 and 2018 [Member]
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Notional amount		$ 2,000					£ 1.3
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Earliest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity		Jan. 31, 2017
Latest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity		Nov. 30, 2018
Derivative Cash Received On Hedge		$ 310
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			$ 31	22
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Notional amount			147
Notional amount of terminated swaps	$ 32
Net cash settlements on terminated interest rate swaps			$ 9
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2,033
LG And E And KU Energy LLC [Member]
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps			$ 0	0	9
LG And E And KU Energy LLC [Member] | LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Notional amount			147
Notional amount of terminated swaps	32
Net cash settlements on terminated interest rate swaps			$ 9
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2,033
Louisville Gas And Electric Co [Member]
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps			$ 0	$ 0	$ 9
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Notional amount			147
Notional amount of terminated swaps	$ 32
Net cash settlements on terminated interest rate swaps			$ 9
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2,033

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities (Fair Values) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Derivatives Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 135	$ 101
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	6	4
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	6	4
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	129	97
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	129	97
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	202	163
Liability value	22	174
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	103	45
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	103	45
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	99	118
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	99	118
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	6	71
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	2	67
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	16	103
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	16	22
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	81
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	20	26
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	16	22
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	16	22
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	20	26
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	16	22
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	$ 16	$ 22

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flow Hedges [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	$ 35	$ (91)	$ 112
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	45	(98)	109
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	4	0	(21)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	(8)	(9)	(7)
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	41	(98)	130
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	42	(82)	116
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	1		3
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0		0
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	11	1	2
Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	145	(267)	377
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	6	5	7
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)	(6)	(7)
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	150	(261)	384
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	6	5	7
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)	(6)	(7)
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	6	5	7
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)	$ (6)	$ (7)

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities (Offsetting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$ 6
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	6
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	337	$ 264
Derivative instruments eligible for offset - assets	2	107
Cash collateral received eligible for offset - assets	40	20
Net assets	295	137
Gross liabilities	22	174
Derivative instruments eligible for offset - liabilities	2	107
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	20	67
LG And E And KU Energy LLC [Member]
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	6
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	6
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	20	26
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	20	26
Louisville Gas And Electric Co [Member]
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	6
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	6
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	20	26
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	$ 20	$ 26

Goodwill and Other Intangible_3

Goodwill and Other Intangible Assets (Goodwill) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	$ 3,258	$ 3,060
Effect of foreign currency exchange rates	(149)	198
Goodwill recognized during the period	53	0
Balance at end of period	3,162	3,258
U.K. Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	2,596	2,398
Effect of foreign currency exchange rates	(149)	198
Goodwill recognized during the period	0	0
Balance at end of period	2,447	2,596
Kentucky Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	662	662
Goodwill recognized during the period	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	0	0
Goodwill recognized during the period	53	0
Balance at end of period	$ 53	$ 0

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets (Other Intangibles) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Subject to amortization: [Abstract]
Gross carrying amount	$ 576	$ 528
Accumulated amortization	204	190
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	345	359
Gross carrying amount - other intangible assets	921	887
Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	339	359
Other [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	6	0
Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	137	138
Accumulated amortization	75	67
Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	418	382
Accumulated amortization	128	120
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	21	8
Accumulated amortization	1	3
Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	7	6	$ 6
Forecasted amortization in 2019	7
Forecasted amortization in 2020	7
Forecasted amortization in 2021	7
Forecasted amortization in 2022	7
Forecasted amortization in 2023	7
Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	8	9	24
Forecasted amortization in 2019	9
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	15	15	30
Forecasted amortization in 2019	16
Forecasted amortization in 2020	15
Forecasted amortization in 2021	15
Forecasted amortization in 2022	15
Forecasted amortization in 2023	15
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount	365	364
Accumulated amortization	122	118
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets	382	377
PPL Electric Utilities Corp [Member] | Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	17	13
PPL Electric Utilities Corp [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	363	361
Accumulated amortization	121	117
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	2	3
Accumulated amortization	1	1
LG And E And KU Energy LLC [Member]
Subject to amortization: [Abstract]
Gross carrying amount	147	147
Accumulated amortization	69	61
LG And E And KU Energy LLC [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	21	21
Accumulated amortization	3	3
LG And E And KU Energy LLC [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	126	126
Accumulated amortization	66	58
LG And E And KU Energy LLC [Member] | Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	0	0	1
LG And E And KU Energy LLC [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	8	9	24
Forecasted amortization in 2019	9
Forecasted amortization in 2020	8
Forecasted amortization in 2021	8
Forecasted amortization in 2022	8
Forecasted amortization in 2023	8
LG And E And KU Energy LLC [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	8	9	25
Louisville Gas And Electric Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	94	94
Accumulated amortization	47	41
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	87	87
Accumulated amortization	46	40
Louisville Gas And Electric Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	6	6	13
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	53	53
Accumulated amortization	22	20
Kentucky Utilities Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	14	14
Accumulated amortization	2	2
Kentucky Utilities Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	39	39
Accumulated amortization	20	18
Kentucky Utilities Co [Member] | Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	0	0	1
Kentucky Utilities Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	2	3	11
Forecasted amortization in 2019	3
Forecasted amortization in 2020	2
Forecasted amortization in 2021	2
Forecasted amortization in 2022	2
Forecasted amortization in 2023	2
Kentucky Utilities Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	$ 2	$ 3	$ 12

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 397	$ 488
Accretion	20	21
Obligations incurred	8	0
Changes in estimated cash flow or settlement date	(3)	(73)
Effect of foreign currency exchange rates	(3)	4
Obligations settled	(72)	(43)
Balance at End of Period	347	397
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	356	433
Accretion	18	20
Obligations incurred	8	0
Changes in estimated cash flow or settlement date	(14)	(54)
Effect of foreign currency exchange rates	0	0
Obligations settled	(72)	(43)
Balance at End of Period	296	356
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	121	145
Accretion	6	7
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	(2)	(8)
Effect of foreign currency exchange rates	0	0
Obligations settled	(22)	(23)
Balance at End of Period	103	121
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	235	288
Accretion	12	13
Obligations incurred	8	0
Changes in estimated cash flow or settlement date	(12)	(46)
Effect of foreign currency exchange rates	0	0
Obligations settled	(50)	(20)
Balance at End of Period	$ 193	$ 235

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	$ (3,422)	$ (3,778)	$ (2,728)
Amounts arising during the year	(606)	151	(1,080)
Reclassifications from AOCI	115	205	30
Net OCI during the year	(491)	356	(1,050)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(51)
Balance at end of year	(3,964)	(3,422)	(3,778)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(1,089)	(1,627)	(520)
Amounts arising during the year	(444)	538	(1,107)
Reclassifications from AOCI	0	0	0
Net OCI during the year	(444)	538	(1,107)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	0
Balance at end of year	(1,533)	(1,089)	(1,627)
Qualifying Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(13)	(7)	(7)
Amounts arising during the year	36	(79)	91
Reclassifications from AOCI	(29)	73	(91)
Net OCI during the year	7	(6)	0
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(1)
Balance at end of year	(7)	(13)	(7)
Equity Investees AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	(1)	0
Amounts arising during the year	0	0	0
Reclassifications from AOCI	0	1	(1)
Net OCI during the year	0	1	(1)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	0
Balance at end of year	0	0	(1)
Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(7)	(8)	(6)
Amounts arising during the year	(11)	0	(3)
Reclassifications from AOCI	2	1	1
Net OCI during the year	(9)	1	(2)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(3)
Balance at end of year	(19)	(7)	(8)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(2,313)	(2,135)	(2,195)
Amounts arising during the year	(187)	(308)	(61)
Reclassifications from AOCI	142	130	121
Net OCI during the year	(45)	(178)	60
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(47)
Balance at end of year	(2,405)	(2,313)	(2,135)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(88)	(70)	(46)
Amounts arising during the year	7	(25)	(27)
Reclassifications from AOCI	10	7	3
Net OCI during the year	17	(18)	(24)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(18)
Balance at end of year	(89)	(88)	(70)
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	(1)	0
Amounts arising during the year	0	0	0
Reclassifications from AOCI	0	1	(1)
Net OCI during the year	0	1	(1)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	0
Balance at end of year	0	0	(1)
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)	(8)	(10)
Amounts arising during the year	0	(2)	0
Reclassifications from AOCI	2	1	2
Net OCI during the year	2	(1)	2
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(2)
Balance at end of year	(9)	(9)	(8)
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	(79)	(61)	(36)
Amounts arising during the year	7	(23)	(27)
Reclassifications from AOCI	8	5	2
Net OCI during the year	15	(18)	(25)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment	(16)
Balance at end of year	$ (80)	$ (79)	$ (61)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Affected Line Item on the Statements of Income
Interest Expense	$ (963)	$ (901)	$ (888)
Other Income (Expense) - net	396	(88)	502
Total Pre-tax	2,285	1,912	2,550
Income Taxes	(458)	(784)	(648)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total After-Tax	(115)	(205)	(30)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	35	(91)	112
Income Taxes	(6)	18	(21)
Total After-Tax	29	(73)	91
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	(8)	(9)	(7)
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	1	0	3
Other Income (Expense) - net	42	(82)	116
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	(1)	1
Total Pre-tax	0	(1)	1
Income Taxes	0	0	0
Total After-Tax	0	(1)	1
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(180)	(169)	(158)
Income Taxes	36	38	36
Total After-Tax	(144)	(131)	(122)
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	(2)	(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	$ (178)	$ (167)	$ (156)

New Accounting Guidance Pendi_3

New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Details) - Forecast [Member] - Accounting Standards Update 2016-02 [Member] $ in Millions	Jan. 01, 2019USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 80
Current Lease Liability	25
Noncurrent Lease Liability	65
LG And E And KU Energy LLC [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	55
Current Lease Liability	20
Noncurrent Lease Liability	45
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	25
Current Lease Liability	10
Noncurrent Lease Liability	15
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	30
Current Lease Liability	10
Noncurrent Lease Liability	$ 25

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, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Revenues [Abstract]
Operating Revenues	$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 1,926	$ 1,845	$ 1,725	$ 1,951	$ 7,785	$ 7,447	$ 7,517
Operating Expenses [Abstract]
Other operation and maintenance									1,983	1,802	1,857
Total Operating Expenses									4,933	4,546	4,581
Operating Loss	657	686	658	851	749	736	658	758	2,852	2,901	2,936
Other Income (Expense) - net [Abstract]
Other Income (Expense) - net									396	(88)	502
Interest Expense									963	901	888
Income Before Income Taxes									2,285	1,912	2,550
Income Taxes									458	784	648
Net income	$ 415	$ 445	$ 515	$ 452	$ 78	$ 355	$ 292	$ 403	1,827	1,128	1,902
Total other comprehensive income (loss)									(491)	356	(1,050)
Comprehensive Income Attributable to PPL Shareowners									$ 1,336	$ 1,484	$ 852
Net Income Available to PPL Corporation Common Shareowners: (in dollars per share)
Basic (in dollars per share)	$ 0.57	$ 0.63	$ 0.74	$ 0.65	$ 0.11	$ 0.52	$ 0.43	$ 0.59	$ 2.59	$ 1.64	$ 2.80
Diluted (in dollars per share)	$ 0.57	$ 0.62	$ 0.73	$ 0.65	$ 0.11	$ 0.51	$ 0.43	$ 0.59	$ 2.58	$ 1.64	$ 2.79
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic									704,439	685,240	677,592
Diluted									708,619	687,334	680,446
LG&E and KU Energy LLC Unconsolidated [Member]
Other Income (Expense) - net [Abstract]
Equity in earnings of subsidiaries									$ 470	$ 397	$ 452
Interest Income from Affiliate									25	14	9
Other Income (Expense) - net									495	411	461
Interest Expense									29	30	29
Interest Expense with Affiliates									28	20	18
Income Before Income Taxes									438	361	414
Income Taxes									(7)	45	(15)
Net income									445	316	429
Total other comprehensive income (loss)									17	(18)	(24)
Comprehensive Income Attributable to PPL Shareowners									$ 462	$ 298	$ 405

SCHEDULE I - CONDENSED UNCONS_3

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flows from Operating Activities [Abstract]
Net cash provided by (used in) operating activities	$ 2,821	$ 2,461	$ 2,890
Cash Flows from Investing Activities [Abstract]
Net cash provided by (used in) investing activities	(3,361)	(3,161)	(2,926)
Cash Flows from Financing Activities [Abstract]
Issuance of equity, net of issuance costs	698	453	144
Net increase (decrease) in short-term debt	363	115	29
Retirement of long-term debt	(277)	(168)	(930)
Issuance of long-term debt	1,059	1,515	1,342
Payment of common stock dividends	(1,133)	(1,072)	(1,030)
Other	(20)	(19)	6
Net cash provided by (used in) financing activities	690	824	(439)
Cash and Cash Equivalents at Beginning of Period	485
Cash and Cash Equivalents at End of Period	621	485
LG&E and KU Energy LLC Unconsolidated [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	346	401	285
Cash Flows from Investing Activities [Abstract]
Capital contributions to affiliated subsidiaries	(128)	(30)	(91)
Net decrease (increase) in notes receivable from affiliates	(26)	(28)	47
Net cash provided by (used in) investing activities	(154)	(58)	(44)
Cash Flows from Financing Activities [Abstract]
Net increase (decrease) in notes payable to affiliates	110	58	90
Net increase (decrease) in short-term debt	0	0	(75)
Contributions from member	0	0	61
Distributions to member	(302)	(402)	(316)
Net cash provided by (used in) financing activities	(192)	(344)	(240)
Net Increase (Decrease) in Cash and Cash Equivalents	0	(1)	1
Cash and Cash Equivalents at Beginning of Period	0	1	0
Cash and Cash Equivalents at End of Period	0	0	1
Supplemental Disclosures of Cash Flow Information: [Abstract]
Cash Dividends Received from Subsidiaries	$ 402	$ 418	$ 376

SCHEDULE I - CONDENSED UNCONS_4

SCHEDULE I - CONDENSED UNCONSOLIDATED BALANCE SHEETS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents		$ 621	$ 485
Accounts Receivable [Abstract]
Other		107	100
Accounts receivable		663	681
Prepayments		70	66
Price risk management assets		109	49
Other current assets		63	50
Total Current Assets		2,432	2,294
Other Noncurrent Assets [Abstract]
Price risk management assets		228	215
Other noncurrent assets		192	135
Total Other Noncurrent Assets		6,506	6,093
Total Assets		43,396	41,479
Current Liabilities [Abstract]
Short-term debt		1,430	1,080
Long-term debt due within one year		530	348
Dividends		296	273
Taxes		110	105
Other current liabilities		551	624
Total Current Liabilities		4,563	4,023
Long-term Debt [Abstract]
Total Long-term Debt		20,069	19,847
Total Deferred Credits and Other Noncurrent Liabilities		7,107	6,848
Equity [Abstract]
Common stock	[1]	7	7
Additional paid-in capital		11,021	10,305
Earnings reinvested		4,593	3,871
Accumulated other comprehensive loss		(3,964)	(3,422)	$ (3,778)	$ (2,728)
Total Equity		11,657	10,761	9,899	9,919
Total Liabilities and Equity		$ 43,396	$ 41,479
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		720,323	693,398
Common stock shares outstanding		720,323	693,398
LG&E and KU Energy LLC Unconsolidated [Member]
Current Assets
Cash and cash equivalents		$ 0	$ 0	$ 1	$ 0
Accounts Receivable [Abstract]
Accounts receivable		0	1
Accounts receivable from affiliates		0	8
Income Taxes Receivable, Current		0	1
Notes receivable from affiliates		1,061	1,035
Total Current Assets		1,061	1,045
Investments [Abstract]
Affiliated companies at equity		5,422	5,209
Other Noncurrent Assets [Abstract]
Deferred income taxes		299	263
Total Assets		6,782	6,517
Current Liabilities [Abstract]
Notes payable to affiliates		177	241
Accounts payable with affiliates		487	469
Taxes		11	35
Other current liabilities		6	5
Total Current Liabilities		681	750
Long-term Debt [Abstract]
Long-term debt		723	722
Notes payable to affiliates		650	476
Total Long-term Debt		1,373	1,198
Total Deferred Credits and Other Noncurrent Liabilities		5	6
Equity [Abstract]
Members Equity		4,723	4,563
Total Liabilities and Equity		$ 6,782	$ 6,517
[1]	1,560,000 shares authorized; 720,323 and 693,398 shares issued and outstanding at December 31, 2018 and December 31, 2017.

SCHEDULE I - NOTES TO CONDENSED

SCHEDULE I - NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Condensed Unconsolidated Financial Statements [Line Items]
2,020	$ 1,266
Aggregate maturities of long-term debt (Details) [Abstract]
2,021	1,274
Principal outstanding	20,694	$ 20,282
Thereafter	14,143
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Maximum exposure	$ 200
Expiration date	2,021
Term of guarantee (in years)	12 years
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LG&E and KU Energy LLC Unconsolidated [Member] | Senior Unsecured Notes [Member]
Condensed Unconsolidated Financial Statements [Line Items]
2,020	475
Aggregate maturities of long-term debt (Details) [Abstract]
2,021	$ 250
Maturity date (in years)	Dec. 31, 2021
Maturity date (in years)	Dec. 31, 2020
LG&E and KU Energy LLC Unconsolidated [Member] | Note Payable [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Maturity date (in years)	Dec. 31, 2028
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)	12
Expiration date minimum	2,021
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, 2017	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 1,939	$ 1,872	$ 1,848	$ 2,126	$ 1,926	$ 1,845	$ 1,725	$ 1,951	$ 7,785		$ 7,447		$ 7,517
Operating income		657	686	658	851	749	736	658	758	2,852		2,901		2,936
Net income		$ 415	$ 445	$ 515	$ 452	$ 78	$ 355	$ 292	$ 403	$ 1,827		$ 1,128		$ 1,902
Net income (loss) available to PPL common shareowners: [Abstract]
Basic (in dollars per share)		$ 0.57	$ 0.63	$ 0.74	$ 0.65	$ 0.11	$ 0.52	$ 0.43	$ 0.59	$ 2.59		$ 1.64		$ 2.80
Diluted (in dollars per share)		0.57	0.62	0.73	0.65	0.11	0.51	0.43	0.59	2.58		1.64		2.79
Dividends declared per share of common stock (in dollars per share)	$ 0.410	$ 0.41	$ 0.41	$ 0.41	$ 0.41	$ 0.395	$ 0.395	$ 0.395	$ 0.395	$ 1.64		$ 1.58		$ 1.52
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 573	$ 548	$ 517	$ 639	$ 575	$ 547	$ 500	$ 573	$ 2,277		$ 2,195		$ 2,156
Operating income		155	178	133	228	196	189	155	160	694		700		661
Net income		$ 96	$ 111	$ 75	$ 148	$ 111	$ 95	$ 77	$ 79	$ 430	[1]	$ 362	[1]	$ 340	[1]
[1]	Net income equals comprehensive income.