PPL Electric Utilities 10-Q 1 Nov 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 25, 2018
Document Entity Information [Line Items]
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Amendment Flag	false
Entity Registrant Name	PPL Corp
Entity Central Index Key	922,224
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		720,199,922
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
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 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 Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
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 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 Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		37,817,878

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Operating Revenues
Operating Revenues		$ 1,872	$ 1,845	$ 5,846	$ 5,521
Operation
Fuel		206	202	609	576
Energy purchases		149	143	538	494
Other operation and maintenance		479	438	1,453	1,340
Depreciation		275	257	817	745
Taxes, other than income		77	69	234	214
Total Operating Expenses		1,186	1,109	3,651	3,369
Operating Income		686	736	2,195	2,152
Other Income (Expense) - net		106	(35)	297	(112)
Interest Expense		244	230	718	669
Income Before Income Taxes		548	471	1,774	1,371
Income Taxes		103	116	362	321
Net Income		$ 445	$ 355	$ 1,412	$ 1,050
Net Income:
Basic (in dollars per share)		$ 0.63	$ 0.52	$ 2.02	$ 1.53
Diluted (in dollars per share)		0.62	0.51	2.01	1.53
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.41	$ 0.395	$ 1.23	$ 1.185
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		703,730	686,563	699,117	683,783
Diluted (in shares)		710,517	688,746	702,305	686,081
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 548	$ 547	$ 1,704	$ 1,620
Operation
Energy purchases		127	121	403	374
Other operation and maintenance		127	133	419	435
Depreciation		89	77	262	228
Taxes, other than income		27	27	81	79
Total Operating Expenses		370	358	1,165	1,116
Operating Income		178	189	539	504
Other Income (Expense) - net		5	4	18	8
Interest Income from Affiliate		4	2	5	3
Interest Expense		41	36	117	105
Income Before Income Taxes		146	159	445	410
Income Taxes		35	64	111	159
Net Income	[1]	111	95	334	251
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		802	818	2,417	2,350
Operation
Fuel		206	202	609	576
Energy purchases		22	22	135	120
Other operation and maintenance		216	197	632	594
Depreciation		119	114	354	324
Taxes, other than income		18	17	53	49
Total Operating Expenses		581	552	1,783	1,663
Operating Income		221	266	634	687
Other Income (Expense) - net		0	(1)	(2)	(9)
Interest Expense		52	49	154	148
Interest Expense with Affiliate		7	5	18	13
Income Before Income Taxes		162	211	460	517
Income Taxes		32	79	102	195
Net Income		130	132	358	322
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		357	361	1,095	1,055
Electric revenue from affiliate		5	2	21	23
Operating Revenues		362	363	1,116	1,078
Operation
Fuel		83	76	234	225
Energy purchases		17	18	121	107
Energy purchases from affiliate		2	3	10	8
Other operation and maintenance		95	87	277	258
Depreciation		49	47	146	136
Taxes, other than income		9	8	27	25
Total Operating Expenses		255	239	815	759
Operating Income		107	124	301	319
Other Income (Expense) - net		(3)	(3)	(5)	(6)
Interest Expense		20	17	57	53
Income Before Income Taxes		84	104	239	260
Income Taxes		18	39	51	99
Net Income	[1]	66	65	188	161
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		445	457	1,322	1,295
Electric revenue from affiliate		2	3	10	8
Operating Revenues		447	460	1,332	1,303
Operation
Fuel		123	126	375	351
Energy purchases		5	4	14	13
Energy purchases from affiliate		5	2	21	23
Other operation and maintenance		114	104	331	312
Depreciation		70	67	208	188
Taxes, other than income		9	9	26	24
Total Operating Expenses		326	312	975	911
Operating Income		121	148	357	392
Other Income (Expense) - net		1	0	1	(4)
Interest Expense		24	24	74	72
Income Before Income Taxes		98	124	284	316
Income Taxes		21	47	59	120
Net Income	[2]	$ 77	$ 77	$ 225	$ 196
[1]	Net income equals comprehensive income.
[2]	Net income approximates comprehensive income.

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Net Income	$ 445	$ 355	$ 1,412	$ 1,050
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	(187)	(12)	(321)	195
Qualifying derivatives, net of tax	22	1	21	(29)
Defined benefit plans:
Prior service costs, net of tax	0	0	(1)	0
Net actuarial gain (loss), net of tax	(8)	(3)	(9)	(14)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	(14)	0	(21)	24
Equity investees' other comprehensive (income) loss, net of tax	0	0	0	1
Defined benefit plans:
Prior service costs, net of tax	0	0	1	1
Net actuarial (gain) loss, net of tax	34	34	104	97
Total other comprehensive income (loss)	(153)	20	(226)	275
Comprehensive income	292	375	1,186	1,325
LG And E And KU Energy LLC [Member]
Net Income	130	132	358	322
Defined benefit plans:
Net actuarial gain (loss), net of tax	0	(1)	0	(12)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax	0	0	0	1
Defined benefit plans:
Prior service costs, net of tax	1	0	2	1
Net actuarial (gain) loss, net of tax	1	1	2	3
Total other comprehensive income (loss)	2	0	4	(7)
Comprehensive income	$ 132	$ 132	$ 362	$ 315

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Tax effect of foreign currency translation adjustments arising during the period	$ 0	$ 0	$ (2)	$ (1)
Tax effect of qualifying derivatives arising during the period	(5)	0	(5)	7
Tax effect of defined benefit plans - prior service costs arising during period	0	0	0	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	3	2	3	9
Tax effect of qualifying derivatives reclassified from accumulated other comprehensive income (loss)	3	1	4	(6)
Tax effect of equity investees' other comprehensive (income) loss reclassified from accumulated other comprehensive income (loss)	0	0	0	0
Tax effect of prior service costs reclassified from accumulated other comprehensive income (loss)	(1)	(1)	(1)	(1)
Tax effect of net actuarial (gain) loss reclassified from accumulated other comprehensive income (loss)	(8)	(10)	(26)	(28)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	0	0	0	7
Tax effect of equity investees' other comprehensive (income) loss reclassified from accumulated other comprehensive income (loss)	0	0	0	0
Tax effect of prior service costs reclassified from accumulated other comprehensive income (loss)	0	(1)	0	(1)
Tax effect of net actuarial (gain) loss reclassified from accumulated other comprehensive income (loss)	$ 0	$ 0	$ (1)	$ (2)

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017
Cash Flows from Operating Activities
Net Income		$ 1,412	$ 1,050
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		817	745
Amortization		56	72
Defined benefit plans - (income) expense		(146)	(69)
Deferred income taxes and investment tax credits		255	284
Unrealized (gains) losses on derivatives, and other hedging activities		(129)	194
Stock-based compensation expense		21	30
Other		(12)	(8)
Change in current assets and current liabilities
Accounts receivable		38	25
Accounts payable		(55)	(93)
Unbilled revenues		129	81
Fuel, materials and supplies		25	35
Prepayments		(38)	(37)
Taxes payable		20	6
Regulatory assets and liabilities, net		39	(3)
Accrued interest		48	49
Other current liabilities		(36)	(53)
Other		(21)	5
Other operating activities
Defined benefit plans - funding		(284)	(558)
Proceeds from transfer of excess benefit funding		65	0
Other assets		(38)	4
Other liabilities		44	(5)
Net cash provided by operating activities		2,210	1,754
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(2,344)	(2,152)
Purchase of available-for-sale securities		(65)	0
Other investing activities		(57)	(16)
Net cash used in investing activities		(2,466)	(2,168)
Cash Flows from Financing Activities
Issuance of long-term debt		602	1,088
Retirement of long-term debt		(277)	(60)
Issuance of common stock		678	275
Payment of common stock dividends		(846)	(800)
Net increase (decrease) in short-term debt		481	269
Other financing activities		(20)	(34)
Net cash provided by (used in) financing activities		618	738
Effect of Exchange Rate on Cash, Cash Equivalents and Restricted Cash		(9)	7
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		353	331
Cash and Cash Equivalents at Beginning of Period		485
Cash and Cash Equivalents at End of Period		842
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		511	365
Cash, Cash Equivalents and Restricted Cash at End of Period		864	696
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		311	373
Accrued expenditures for intangible assets at September 30,		70	60
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net Income	[1]	334	251
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		262	228
Amortization		17	25
Defined benefit plans - (income) expense		2	10
Deferred income taxes and investment tax credits		77	129
Other		(13)	(8)
Change in current assets and current liabilities
Accounts receivable		22	7
Accounts payable		(46)	(38)
Unbilled revenues		45	30
Prepayments		(25)	(31)
Taxes payable		(1)	10
Regulatory assets and liabilities, net		(25)	0
Other		12	(9)
Other operating activities
Defined benefit plans - funding		(28)	(24)
Other assets		(37)	(2)
Other liabilities		54	(3)
Net cash provided by operating activities		650	575
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(835)	(851)
Net decrease in notes receivable from affiliate		0	(2)
Other investing activities		(2)	(5)
Net cash used in investing activities		(837)	(858)
Cash Flows from Financing Activities
Issuance of long-term debt		398	470
Net increase (decrease) in short-term debt		0	(295)
Contributions from parent		429	575
Payment of common stock dividends to parent		(271)	(231)
Other financing activities		(4)	(6)
Net cash provided by (used in) financing activities		552	513
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		365	230
Cash and Cash Equivalents at Beginning of Period		49
Cash and Cash Equivalents at End of Period		414
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51	15
Cash, Cash Equivalents and Restricted Cash at End of Period		416	245
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		171	190
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net Income		358	322
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		354	324
Amortization		13	19
Defined benefit plans - (income) expense		12	19
Deferred income taxes and investment tax credits		71	173
Other		(2)	1
Change in current assets and current liabilities
Accounts receivable		8	18
Accounts payable		4	(30)
Accounts payable to affiliates		7	3
Unbilled revenues		54	19
Fuel, materials and supplies		17	34
Taxes payable		(11)	13
Regulatory assets and liabilities, net		62	(3)
Accrued interest		41	41
Other		(36)	2
Other operating activities
Defined benefit plans - funding		(126)	(32)
Expenditures for asset retirement obligations		(46)	(22)
Other assets		(1)	5
Other liabilities		8	14
Net cash provided by operating activities		787	920
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(826)	(579)
Other investing activities		1	4
Net cash used in investing activities		(825)	(575)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate		(145)	(4)
Issuance of long-term debt with affiliate		250	0
Issuance of long-term debt		118	60
Retirement of long-term debt		(27)	(60)
Distributions to member		(217)	(316)
Net increase (decrease) in short-term debt		60	5
Other financing activities		(2)	(3)
Net cash provided by (used in) financing activities		37	(318)
Cash and Cash Equivalents, Period Increase (Decrease)		(1)	27
Cash and Cash Equivalents at Beginning of Period		30	13
Cash and Cash Equivalents at End of Period		29	40
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		108	142
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net Income	[1]	188	161
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		146	136
Amortization		10	11
Defined benefit plans - (income) expense		2	5
Deferred income taxes and investment tax credits		46	96
Change in current assets and current liabilities
Accounts receivable		14	12
Accounts receivable from affiliates		2	6
Accounts payable		14	(12)
Accounts payable to affiliates		(2)	(10)
Unbilled revenues		30	11
Fuel, materials and supplies		9	6
Taxes payable		4	(15)
Regulatory assets and liabilities, net		24	(2)
Accrued interest		13	12
Other		(14)	8
Other operating activities
Defined benefit plans - funding		(59)	(3)
Expenditures for asset retirement obligations		(17)	(13)
Other assets		0	5
Other liabilities		0	4
Net cash provided by operating activities		410	418
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(420)	(293)
Net cash used in investing activities		(420)	(293)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate		0	10
Issuance of long-term debt		100	60
Retirement of long-term debt		0	(60)
Net increase (decrease) in short-term debt		(23)	21
Contributions from parent		43	0
Payment of common stock dividends to parent		(113)	(150)
Other financing activities		(1)	(2)
Net cash provided by (used in) financing activities		6	(121)
Cash and Cash Equivalents, Period Increase (Decrease)		(4)	4
Cash and Cash Equivalents at Beginning of Period		15	5
Cash and Cash Equivalents at End of Period		11	9
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		51	83
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net Income	[2]	225	196
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		208	188
Amortization		2	7
Defined benefit plans - (income) expense		0	3
Deferred income taxes and investment tax credits		37	116
Other		(2)	0
Change in current assets and current liabilities
Accounts receivable		2	6
Accounts receivable from affiliates		0	(1)
Accounts payable		(2)	(6)
Accounts payable to affiliates		(8)	(16)
Unbilled revenues		24	8
Fuel, materials and supplies		8	28
Taxes payable		11	(21)
Regulatory assets and liabilities, net		38	(1)
Accrued interest		21	22
Other		(4)	(5)
Other operating activities
Defined benefit plans - funding		(53)	(22)
Expenditures for asset retirement obligations		(29)	(9)
Other assets		(1)	0
Other liabilities		8	8
Net cash provided by operating activities		485	501
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(405)	(283)
Net increase in notes receivable with affiliates		0	(10)
Other investing activities		1	4
Net cash used in investing activities		(404)	(289)
Cash Flows from Financing Activities
Issuance of long-term debt		18	0
Retirement of long-term debt		(27)	0
Net increase (decrease) in short-term debt		83	(16)
Contributions from parent		45	0
Payment of common stock dividends to parent		(196)	(171)
Other financing activities		(1)	(1)
Net cash provided by (used in) financing activities		(78)	(188)
Cash and Cash Equivalents, Period Increase (Decrease)		3	24
Cash and Cash Equivalents at Beginning of Period		15	7
Cash and Cash Equivalents at End of Period		18	31
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		$ 57	$ 58
[1]	Net income equals comprehensive income.
[2]	Net income approximates comprehensive income.

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Sep. 30, 2018	Dec. 31, 2017
Assets, Current [Abstract]
Cash and cash equivalents		$ 842	$ 485
Accounts receivable (less reserve:)
Customer		684	681
Other		58	100
Unbilled revenues		411	543
Fuel, materials and supplies		295	320
Prepayments		103	66
Price risk management assets		91	49
Regulatory assets		29	34
Other current assets		61	50
Total Current Assets		2,545	2,294
Property, Plant and Equipment
Regulated utility plant		39,144	38,228
Less: accumulated depreciation - regulated utility plant		7,196	6,785
Regulated utility plant, net		31,948	31,443
Non-regulated property, plant and equipment		365	384
Less: accumulated depreciation - non-regulated property, plant and equipment		111	110
Non-regulated property, plant and equipment, net		254	274
Construction work in progress		1,816	1,375
Property, Plant and Equipment, net		34,018	33,092
Other Noncurrent Assets
Regulatory assets		1,525	1,504
Goodwill		3,242	3,258
Other intangibles		700	697
Pension benefit asset		615	284
Price risk management assets		206	215
Other noncurrent assets		191	135
Total Other Noncurrent Assets		6,479	6,093
Total Assets		43,042	41,479
Current Liabilities
Short-term debt		1,549	1,080
Long-term debt due within one year		330	348
Accounts payable		814	924
Taxes		121	105
Interest		326	282
Dividends		287	273
Customer deposits		265	292
Regulatory liabilities		136	95
Other current liabilities		555	624
Total Current Liabilities		4,383	4,023
Long-term Debt
Long-term Debt		19,924	19,847
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		2,717	2,462
Investment tax credits		127	129
Accrued pension obligations		649	800
Asset retirement obligations		279	312
Regulatory liabilities		2,739	2,704
Other deferred credits and noncurrent liabilities		441	441
Total Deferred Credits and Other Noncurrent Liabilities		6,952	6,848
Commitments and Contingent Liabilities
Equity
Common stock	[1]	7	7
Additional paid-in capital		11,001	10,305
Earnings reinvested		4,423	3,871
Accumulated other comprehensive loss		(3,648)	(3,422)
Total Equity		11,783	10,761
Total Liabilities and Equity		43,042	41,479
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		414	49
Accounts receivable (less reserve:)
Customer		309	279
Other		18	71
Accounts receivable from affiliates		11	0
Unbilled revenues		82	127
Fuel, materials and supplies		26	34
Prepayments		31	6
Regulatory assets		18	16
Other current assets		10	6
Total Current Assets		919	588
Property, Plant and Equipment
Regulated utility plant		11,332	10,785
Less: accumulated depreciation - regulated utility plant		2,848	2,778
Regulated utility plant, net		8,484	8,007
Construction work in progress		643	508
Property, Plant and Equipment, net		9,127	8,515
Other Noncurrent Assets
Regulatory assets		738	709
Other intangibles		260	259
Other noncurrent assets		52	11
Total Other Noncurrent Assets		1,050	979
Total Assets		11,096	10,082
Current Liabilities
Accounts payable		384	386
Accounts payable to affiliates		25	31
Taxes		7	8
Interest		43	36
Regulatory liabilities		72	86
Other current liabilities		99	98
Total Current Liabilities		630	645
Long-term Debt
Long-term Debt		3,693	3,298
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,258	1,154
Accrued pension obligations		210	246
Regulatory liabilities		686	668
Other deferred credits and noncurrent liabilities		135	79
Total Deferred Credits and Other Noncurrent Liabilities		2,289	2,147
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		3,158	2,729
Earnings reinvested		962	899
Total Equity		4,484	3,992
Total Liabilities and Equity		11,096	10,082
LG And E And KU Energy LLC [Member]
Assets, Current [Abstract]
Cash and cash equivalents		29	30
Accounts receivable (less reserve:)
Customer		230	246
Other		47	44
Unbilled revenues		149	203
Fuel, materials and supplies		238	254
Prepayments		32	25
Regulatory assets		11	18
Other current assets		7	8
Total Current Assets		743	828
Property, Plant and Equipment
Regulated utility plant		13,438	13,187
Less: accumulated depreciation - regulated utility plant		2,031	1,785
Regulated utility plant, net		11,407	11,402
Construction work in progress		1,000	627
Property, Plant and Equipment, net		12,407	12,029
Other Noncurrent Assets
Regulatory assets		787	795
Goodwill		996	996
Other intangibles		80	86
Other noncurrent assets		75	68
Total Other Noncurrent Assets		1,938	1,945
Total Assets		15,088	14,802
Current Liabilities
Short-term debt		304	244
Long-term debt due within one year		330	98
Notes payable with affiliates		80	225
Accounts payable		271	338
Accounts payable to affiliates		14	7
Taxes		55	66
Price risk management liabilities		4	4
Interest		73	32
Customer deposits		60	58
Regulatory liabilities		64	9
Asset retirement obligations		86	85
Other current liabilities		127	161
Total Current Liabilities		1,468	1,327
Long-term Debt
Long-term debt		4,521	4,661
Long-term debt to affiliate		650	400
Long-term Debt		5,171	5,061
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		922	866
Investment tax credits		127	129
Accrued pension obligations		256	365
Asset retirement obligations		231	271
Regulatory liabilities		2,053	2,036
Price risk management liabilities		15	22
Other deferred credits and noncurrent liabilities		137	162
Total Deferred Credits and Other Noncurrent Liabilities		3,741	3,851
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(84)	(88)
Member's Equity		4,708	4,563
Total Liabilities and Equity		15,088	14,802
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		11	15
Accounts receivable (less reserve:)
Customer		102	116
Other		13	13
Accounts receivable from affiliates		22	24
Unbilled revenues		61	91
Fuel, materials and supplies		122	131
Prepayments		14	11
Regulatory assets		11	12
Other current assets		3	3
Total Current Assets		359	416
Property, Plant and Equipment
Regulated utility plant		5,684	5,587
Less: accumulated depreciation - regulated utility plant		707	614
Regulated utility plant, net		4,977	4,973
Construction work in progress		520	305
Property, Plant and Equipment, net		5,497	5,278
Other Noncurrent Assets
Regulatory assets		400	411
Goodwill		389	389
Other intangibles		49	53
Other noncurrent assets		27	12
Total Other Noncurrent Assets		865	865
Total Assets		6,721	6,559
Current Liabilities
Short-term debt		176	199
Long-term debt due within one year		234	98
Accounts payable		152	179
Accounts payable to affiliates		22	23
Taxes		29	25
Price risk management liabilities		4	4
Interest		24	11
Customer deposits		28	27
Regulatory liabilities		26	3
Asset retirement obligations		21	24
Other current liabilities		39	52
Total Current Liabilities		755	645
Long-term Debt
Long-term Debt		1,574	1,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		611	572
Investment tax credits		35	35
Accrued pension obligations		0	45
Asset retirement obligations		86	97
Regulatory liabilities		920	919
Price risk management liabilities		15	22
Other deferred credits and noncurrent liabilities		80	86
Total Deferred Credits and Other Noncurrent Liabilities		1,747	1,776
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,755	1,712
Earnings reinvested		466	391
Total Equity		2,645	2,527
Total Liabilities and Equity		6,721	6,559
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		18	15
Accounts receivable (less reserve:)
Customer		128	130
Other		25	30
Unbilled revenues		88	112
Fuel, materials and supplies		116	123
Prepayments		17	14
Regulatory assets		0	6
Other current assets		4	5
Total Current Assets		396	435
Property, Plant and Equipment
Regulated utility plant		7,746	7,592
Less: accumulated depreciation - regulated utility plant		1,323	1,170
Regulated utility plant, net		6,423	6,422
Construction work in progress		479	321
Property, Plant and Equipment, net		6,902	6,743
Other Noncurrent Assets
Regulatory assets		387	384
Goodwill		607	607
Other intangibles		31	33
Other noncurrent assets		77	52
Total Other Noncurrent Assets		1,102	1,076
Total Assets		8,400	8,254
Current Liabilities
Short-term debt		128	45
Long-term debt due within one year		96	0
Accounts payable		105	137
Accounts payable to affiliates		47	53
Taxes		30	19
Interest		37	16
Customer deposits		32	31
Regulatory liabilities		38	6
Asset retirement obligations		65	61
Other current liabilities		43	46
Total Current Liabilities		621	414
Long-term Debt
Long-term Debt		2,224	2,328
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		719	691
Investment tax credits		92	94
Accrued pension obligations		0	36
Asset retirement obligations		145	174
Regulatory liabilities		1,133	1,117
Other deferred credits and noncurrent liabilities		35	43
Total Deferred Credits and Other Noncurrent Liabilities		2,124	2,155
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,661	2,616
Earnings reinvested		462	433
Total Equity		3,431	3,357
Total Liabilities and Equity		$ 8,400	$ 8,254
[1]	1,560,000 shares authorized; 719,702 and 693,398 shares issued and outstanding at September 30, 2018 and December 31, 2017.
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at September 30, 2018 and December 31, 2017.
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at September 30, 2018 and December 31, 2017.
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at September 30, 2018 and December 31, 2017.

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 54	$ 51
Equity
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock shares authorized (in shares)	1,560,000	1,560,000
Common stock shares issued (in shares)	719,702	693,398
Common stock shares outstanding (in shares)	719,702	693,398
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 26	$ 24
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	170,000	170,000
Common stock shares issued (in shares)	66,368	66,368
Common stock shares outstanding (in shares)	66,368	66,368
LG And E And KU Energy LLC [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 26	$ 25
Louisville Gas And Electric Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 1	$ 1
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	75,000	75,000
Common stock shares issued (in shares)	21,294	21,294
Common stock shares outstanding (in shares)	21,294	21,294
Kentucky Utilities Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 2	$ 1
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	80,000	80,000
Common stock shares issued (in shares)	37,818	37,818
Common stock shares outstanding (in shares)	37,818	37,818

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) shares in Thousands, $ in Millions		Total	Common Stock [Member]		Additional Paid-in Capital [Member]	Earnings Reinvested [Member]	Accumulated Other Comprehensive Loss [Member]	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member]Common Stock [Member]		PPL Electric Utilities Corp [Member]Additional Paid-in Capital [Member]	PPL Electric Utilities Corp [Member]Earnings Reinvested [Member]	LG And E And KU Energy LLC [Member]	Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member]Common Stock [Member]		Louisville Gas And Electric Co [Member]Additional Paid-in Capital [Member]	Louisville Gas And Electric Co [Member]Earnings Reinvested [Member]	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member]Common Stock [Member]		Kentucky Utilities Co [Member]Additional Paid-in Capital [Member]	Kentucky Utilities Co [Member]Earnings Reinvested [Member]	Kentucky Utilities Co [Member]Accumulated Other Comprehensive Loss [Member]
Balance at beginning of period - shares at Dec. 31, 2016			679,731	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2016		$ 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)
Balance at beginning of period at Dec. 31, 2016														$ 4,667
Common stock shares issued	[1]		8,402
Common stock issued		303			303
Stock-based compensation		(22)			(22)
Net Income		1,050				1,050		251	[5]				251	322	161	[5]				161	196	[6]				196
Capital contributions from parent								575				575
Dividends and dividend equivalents		(813)				(813)
Dividends declared on common stock								(231)					(231)		(150)					(150)	(171)					(171)
Distributions to member														(316)
Other comprehensive income (loss)		275					275							(7)							1						1
Balance at end of period - shares at Sep. 30, 2017			688,133	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at end of period at Sep. 30, 2017		$ 10,692	$ 7		10,122	4,066	(3,503)	$ 3,986		$ 364		2,729	893		$ 2,487		$ 424		1,682	381	$ 3,349		$ 308		2,616	425	0
Balance at end of period at Sep. 30, 2017														4,666
Balance at beginning 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 beginning of period at Dec. 31, 2017		$ 10,761	$ 7		10,305	3,871	(3,422)	$ 3,992		$ 364		2,729	899		$ 2,527		$ 424		1,712	391	$ 3,357		$ 308		2,616	433	0
Balance at beginning of period at Dec. 31, 2017														4,563
Common stock shares issued	[1]		26,304
Common stock issued		699			699
Stock-based compensation		(3)			(3)
Net Income		1,412				1,412		334	[5]				334	358	188	[5]				188	225	[6]				225
Capital contributions from parent								429				429			43				43		45				45
Dividends and dividend equivalents		(860)				(860)
Dividends declared on common stock								$ (271)					(271)		$ (113)					(113)	$ (196)					(196)
Distributions to member														(217)
Other comprehensive income (loss)		$ (226)					(226)							4
Balance at end of period - shares at Sep. 30, 2018		719,702	719,702	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Sep. 30, 2018		$ 11,783	$ 7		$ 11,001	$ 4,423	$ (3,648)	$ 4,484		$ 364		$ 3,158	$ 962		$ 2,645		$ 424		$ 1,755	$ 466	$ 3,431		$ 308		$ 2,661	$ 462	$ 0
Balance at end of period at Sep. 30, 2018														$ 4,708
[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 approximates comprehensive income.

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical)	9 Months Ended
	Sep. 30, 2018vote
Vote per share of PPL's common stock	1

Interim Financial Statements

Interim Financial Statements	9 Months Ended
	Sep. 30, 2018
Interim Financial Statements [Abstract]
Interim Financial Statements	1. Interim Financial Statements (All Registrants) Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed 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. The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, 2017 is derived from that Registrant's 2017 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2017 Form 10-K. The results of operations for the three and nine months ended September 30, 2018 are not necessarily indicative of the results to be expected for the full year ending December 31, 2018 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	2. Summary of Significant Accounting Policies (All Registrants) The following accounting policy disclosures represent updates to Note 1 in each Registrant's 2017 Form 10-K and should be read in conjunction with those disclosures. Income Taxes 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 is 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. 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 the three and nine months ended September 30, 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 September 30, 2018 with respect to the three items discussed above. The Registrants continue to analyze the impact of the TCJA on the deductibility of executive compensation awarded on or before November 2, 2017. The Registrants do not currently anticipate a material change from what was reflected in the December 31, 2017 financial statements and expect to record the impact, if any, of changes in the deductibility of executive compensation in the fourth quarter of 2018. New Accounting Guidance Adopted Accounting for Revenue from Contracts with Customers Effective January 1, 2018, the Registrants adopted accounting guidance that establishes a comprehensive new model for the recognition of revenue from contracts with customers. This model is based on the core principle that revenue should be recognized to depict the transfer of control of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Registrants adopted this guidance using the modified retrospective transition method. No cumulative effect adjustment was required as of the January 1, 2018 adoption date. The adoption of this guidance did not have a material impact on the Registrants' revenue recognition policies. See Note 4 for the required disclosures resulting from the adoption of this standard. Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost Effective January 1, 2018, the Registrants adopted accounting guidance that changes the income statement presentation of net periodic benefit cost. Retrospectively, this guidance requires the service cost component to be disaggregated from other components of net benefit cost and presented in the same income statement line items as other employee compensation costs arising from services rendered during the period. The other components of net periodic benefits are presented separately from the line items that include the service cost and outside of any subtotal of operating income. Prospectively, the guidance limits the capitalization to the service cost component of net periodic benefit costs. For PPL, the non-service cost components of net periodic benefit costs were in a net credit position for the three and nine months ended September 30, 2018 . The non-service cost credits that would have been capitalized under previous guidance, but are now recorded as income within "Other Income (Expense) - net," were $5 million ( $4 million after-tax or $0.01 per share) and $ 16 million ($ 13 million after-tax or $ 0.02 per share) for the three and nine months ended September 30, 2018 . For PPL Electric, LG&E and KU, non-service costs or credits that would have been capitalized under previous guidance are now recognized as a regulatory asset or regulatory liability, as applicable, in accordance with regulatory approvals. 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 on the Statements of Income as a result of the adoption. Three Months Nine Months 2018 2017 2018 2017 PPL $ 61 $ 41 $ 195 $ 123 PPL Electric 1 — 4 — LKE 1 (2 ) 3 (4 ) LG&E — (2 ) (1 ) (4 ) KU — — 2 (1 ) PPL and PPL Electric elected to use the practical expedient that permits using the amounts disclosed in the defined benefit plan note for the prior comparative period as the estimation basis for applying the retrospective presentation requirements. Presentation of Restricted Cash in the Statement of Cash Flows (PPL and PPL Electric) Effective January 1, 2018, PPL and PPL Electric adopted accounting guidance that changes the cash flow statement presentation of restricted cash. Under the new guidance, amounts considered restricted cash are presented with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total cash amounts on the Statements of Cash Flows. The guidance requires a reconciliation of the total cash, cash equivalents and restricted cash from the Statement of Cash Flows to amounts on the Balance Sheets and disclosure of the nature of the restrictions. PPL and PPL Electric have applied this guidance on a retrospective basis for all periods presented. The adoption of this guidance did not have a material impact on the Statements of Cash Flows. Reconciliation of Cash, Cash Equivalents and Restricted Cash The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL PPL Electric September 30, December 31, 2017 September 30, December 31, 2017 Cash and cash equivalents $ 842 $ 485 $ 414 $ 49 Restricted cash - current (a) 3 3 2 2 Restricted cash - noncurrent (a) 19 23 — — Total Cash, Cash Equivalents and Restricted Cash $ 864 $ 511 $ 416 $ 51 (a) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."

Segment and Related Information

Segment and Related Information	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Segment and Related Information	3. Segment and Related Information (PPL) See Note 2 in PPL's 2017 Form 10-K for a discussion of reportable segments and related information. Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended September 30 are as follows: Three Months Nine Months 2018 2017 2018 2017 Operating Revenues from external customers U.K. Regulated $ 517 $ 477 $ 1,716 $ 1,547 Kentucky Regulated 802 818 2,417 2,350 Pennsylvania Regulated 548 547 1,704 1,620 Corporate and Other 5 3 9 4 Total $ 1,872 $ 1,845 $ 5,846 $ 5,521 Net Income U.K. Regulated (a) $ 245 $ 126 $ 836 $ 560 Kentucky Regulated 122 125 332 299 Pennsylvania Regulated 112 95 335 251 Corporate and Other (34 ) 9 (91 ) (60 ) Total $ 445 $ 355 $ 1,412 $ 1,050 (a) Includes unrealized gains and losses from hedging foreign currency economic activity. See Note 14 for additional information. The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: September 30, December 31, Assets U.K. Regulated (a) $ 16,823 $ 16,813 Kentucky Regulated 14,754 14,468 Pennsylvania Regulated 11,110 10,082 Corporate and Other (b) 355 116 Total $ 43,042 $ 41,479 (a) Includes $12.4 billion and $12.5 billion of net PP&E as of September 30, 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 and the elimination of inter-segment transactions. (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	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	4. Revenue from Contracts with Customers (All Registrants) The following is a description of the principal activities from which the Registrants and PPL’s segments generate their revenues. U.K. Regulated Segment Revenue (PPL) 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. Pennsylvania Regulated Segment Revenue (PPL and PPL Electric) 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. Kentucky Regulated Segment Revenue (PPL, LKE, LG&E and KU) 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 tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended September 30, 2018 . Three Months PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 1,872 $ 548 $ 802 $ 362 $ 447 Revenues derived from: Alternative revenue programs (b) (4 ) (3 ) (1 ) (4 ) 3 Other (c) (15 ) (3 ) (5 ) (2 ) (3 ) Revenues from Contracts with Customers $ 1,853 $ 542 $ 796 $ 356 $ 447 Nine Months PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 5,846 $ 1,704 $ 2,417 $ 1,116 $ 1,332 Revenues derived from: Alternative revenue programs (b) 37 (1 ) 38 16 22 Other (c) (43 ) (9 ) (14 ) (5 ) (9 ) Revenues from Contracts with Customers $ 5,840 $ 1,694 $ 2,441 $ 1,127 $ 1,345 (a) PPL includes $517 million and $1.7 billion for the three and nine months ended September 30, 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 3 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 in PPL's 2017 Form 10-K, 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 $442 million and $100 million for the three months ended September 30, 2018 and $1.4 billion and $306 million for the nine months ended September 30, 2018 . The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended September 30, 2018 . Three Months PPL PPL Electric LKE LG&E KU Licensed energy suppliers (a) $ 475 $ — $ — $ — $ — Residential 647 328 319 162 157 Commercial 307 88 219 112 107 Industrial 156 12 144 45 99 Other (b) 119 14 65 27 39 Wholesale - municipal 30 — 30 — 30 Wholesale - other (c) 19 — 19 10 15 Transmission 100 100 — — — Revenues from Contracts with Customers $ 1,853 $ 542 $ 796 $ 356 $ 447 Nine Months PPL PPL Electric LKE LG&E KU Licensed energy suppliers (a) $ 1,606 $ — $ — $ — $ — Residential 2,039 1,036 1,003 505 498 Commercial 928 275 653 343 310 Industrial 466 37 429 134 295 Other (b) 339 40 200 88 113 Wholesale - municipal 91 — 91 — 91 Wholesale - other (c) 65 — 65 57 38 Transmission 306 306 — — — Revenues from Contracts with Customers $ 5,840 $ 1,694 $ 2,441 $ 1,127 $ 1,345 (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. The following table shows the accounts receivable balances that were impaired for the periods ended September 30, 2018 . Three Months Nine Months PPL $ 11 $ 24 PPL Electric 7 17 LKE 4 7 LG&E 2 3 KU 2 4 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 September 30, 2018 40 17 8 4 4 The following table shows the revenue recognized during the period ended September 30, 2018 that was included in the contract liability balance at December 31, 2017. Nine Months PPL $ 22 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 September 30, 2018, PPL had $65 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $44 million within the next 12 months .

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Earnings Per Share	5. 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 September 30 used in the EPS calculation are: Three Months Nine Months 2018 2017 2018 2017 Income (Numerator) Net income $ 445 $ 355 $ 1,412 $ 1,050 Less amounts allocated to participating securities 1 1 2 2 Net income available to PPL common shareowners - Basic and Diluted $ 444 $ 354 $ 1,410 $ 1,048 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 703,730 686,563 699,117 683,783 Add incremental non-participating securities: Share-based payment awards 298 2,183 427 2,298 Forward sale agreements 6,489 — 2,761 — Weighted-average shares - Diluted EPS 710,517 688,746 702,305 686,081 Basic EPS Net Income available to PPL common shareowners $ 0.63 $ 0.52 $ 2.02 $ 1.53 Diluted EPS Net Income available to PPL common shareowners $ 0.62 $ 0.51 $ 2.01 $ 1.53 For the periods ended September 30 , PPL issued common stock related to stock-based compensation plans and the DRIP as follows (in thousands): Three Months Nine Months 2018 2017 2018 2017 Stock-based compensation plans (a) 80 256 568 1,707 DRIP 493 355 1,504 1,169 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock units and conversion of stock units granted to directors. See Note 8 for additional information on common stock issued under the ATM Program and settlement of a portion of the PPL common stock forward sale agreements. For the periods ended September 30 , the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months Nine Months 2018 2017 2018 2017 Stock options 15 696 229 696 Restricted stock units 2 — 15 —

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	6. Income Taxes (All Registrants) Tax Cuts and Jobs Act (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 is 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. 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 the three and nine months ended September 30, 2018 are as follows. Taxable Income (Loss) (a) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision September 30, 2018 Adjustment 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, 2023. 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 September 30, 2018 Adjustment 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 (a) 229 220 9 Total $ 321 $ 321 $ — Income Tax Expense (Benefit) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision September 30, 2018 Adjustment PPL Electric Reduction in U.S. federal income tax rate (a) $ (13 ) $ (13 ) $ — LKE Reduction in U.S. federal income tax rate (a) $ 110 $ 112 $ (2 ) (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 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 September 30, 2018 with respect to the three items discussed above. The Registrants continue to analyze the impact of the TCJA on the deductibility of executive compensation awarded on or before November 2, 2017. The Registrants do not currently anticipate a material change from what was reflected in the December 31, 2017 financial statements and expect to record the impact, if any, of changes in the deductibility of executive compensation in the fourth quarter of 2018. Reconciliations of income taxes for the periods ended September 30 are as follows. (PPL) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 115 $ 165 $ 373 $ 480 Increase (decrease) due to: State income taxes, net of federal income tax benefit 9 14 34 37 Valuation allowance adjustments 5 4 17 9 Impact of lower U.K. income tax rates relative to U.S. income tax rates (a) (7 ) (45 ) (20 ) (133 ) U.S. income tax on foreign earnings - net of foreign tax credit (a) (b) 1 (8 ) 2 (24 ) Federal and state tax reserve adjustments — — 3 — Impact of the U.K. Finance Acts (4 ) (3 ) (7 ) (12 ) Depreciation and other items not normalized (1 ) (2 ) (4 ) (7 ) Amortization of excess deferred income taxes (a) (11 ) — (30 ) — Deferred tax impact of state tax reform (c) — — 9 — Interest benefit on U.K. financing entities (4 ) (4 ) (13 ) (12 ) Stock-based compensation — — 1 (7 ) Other — (5 ) (3 ) (10 ) Total increase (decrease) (12 ) (49 ) (11 ) (159 ) Total income taxes $ 103 $ 116 $ 362 $ 321 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) Lower income taxes in 2017 primarily due to the tax benefit of accelerated pension contributions made in the first quarter of 2017. The related tax benefit was recognized over the annual period as a result of utilizing an estimated annual effective tax rate. (c) During the second quarter of 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. (PPL Electric) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 30 $ 56 $ 93 $ 144 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 9 35 26 Depreciation and other items not normalized (1 ) (1 ) (4 ) (5 ) Amortization of excess deferred income taxes (a) (5 ) — (13 ) — Stock-based compensation — — — (5 ) Other (1 ) — — (1 ) Total increase (decrease) 5 8 18 15 Total income taxes $ 35 $ 64 $ 111 $ 159 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (LKE) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 34 $ 74 $ 97 $ 181 Increase (decrease) due to: State income taxes, net of federal income tax benefit (b) 6 8 17 19 Amortization of investment tax credit (1 ) (1 ) (3 ) (2 ) Deferred tax impact of U.S. tax reform (a) (2 ) — (2 ) — Deferred tax impact of state tax reform (c) — — 9 — Amortization of excess deferred income taxes (a) (3 ) — (14 ) — Other (2 ) (2 ) (2 ) (3 ) Total increase (decrease) (2 ) 5 5 14 Total income taxes $ 32 $ 79 $ 102 $ 195 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018. (c) During the second quarter of 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. (LG&E) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 18 $ 36 $ 50 $ 91 Increase (decrease) due to: State income taxes, net of federal income tax benefit (b) 3 4 9 10 Amortization of excess deferred income taxes (a) (1 ) — (6 ) — Other (2 ) (1 ) (2 ) (2 ) Total increase (decrease) — 3 1 8 Total income taxes $ 18 $ 39 $ 51 $ 99 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018. (KU) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 21 $ 43 $ 60 $ 111 Increase (decrease) due to: State income taxes, net of federal income tax benefit (b) 3 5 10 11 Amortization of excess deferred income taxes (a) (2 ) — (8 ) — Other (1 ) (1 ) (3 ) (2 ) Total increase (decrease) — 4 (1 ) 9 Total income taxes $ 21 $ 47 $ 59 $ 120 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018. Kentucky State Tax Reform (All Registrants) HB 487, which became law on April 27, 2018, provides for significant changes to the Kentucky tax code including (1) adopting mandatory combined reporting for corporate members of unitary business groups for taxable years beginning on or after January 1, 2019 (members of a unitary business group may make an eight-year binding election to file consolidated corporate income tax returns with all members of their federal affiliated group) and (2) a reduction in the Kentucky corporate income tax rate from 6% to 5% for taxable years beginning after December 31, 2017. LKE recognized a deferred tax charge of $9 million in the second quarter of 2018 primarily associated with the remeasurement of non-regulated accumulated deferred income tax balances. As indicated in Note 1 in the Registrants' 2017 Form 10-K, LG&E's and KU's accounting for income taxes is impacted by rate regulation. Therefore, reductions in regulated accumulated deferred income tax balances due to the reduction in the Kentucky corporate income tax rate to 5% under the provisions of HB 487 may result in amounts previously collected from utility customers for these deferred taxes to be refundable to such customers in future periods. In the second quarter of 2018, LG&E and KU recorded the impact of the reduced tax rate, related to the remeasurement of deferred income taxes, as an increase in regulatory liabilities of $16 million and $19 million. In a separate regulatory proceeding, LG&E and KU have requested to begin returning state excess deferred income taxes to customers in conjunction with the 2018 Kentucky base rate case, which was filed on September 28, 2018. See Note 7 for additional information related to the rate case proceedings. PPL is evaluating the impact, if any, of unitary or elective consolidated income tax reporting on all its Registrants.

Utility Rate Regulation

Utility Rate Regulation	9 Months Ended
	Sep. 30, 2018
Regulated Operations [Abstract]
Utility Rate Regulation	7. Utility Rate Regulation (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric September 30, December 31, September 30, December 31, Current Regulatory Assets: Environmental cost recovery $ — $ 5 $ — $ — Generation formula rate — 6 — — Smart meter rider 16 15 16 15 Plant outage costs 7 3 — — Gas supply clause 3 4 — — Other 3 1 2 1 Total current regulatory assets (a) $ 29 $ 34 $ 18 $ 16 PPL PPL Electric September 30, December 31, September 30, December 31, Noncurrent Regulatory Assets: Defined benefit plans $ 847 $ 880 $ 486 $ 504 Taxes recoverable through future rates 3 3 3 3 Storm costs (b) 45 33 22 — Unamortized loss on debt 47 54 23 29 Interest rate swaps 18 26 — — Terminated interest rate swaps 88 92 — — Accumulated cost of removal of utility plant 190 173 190 173 AROs 267 234 — — Act 129 compliance rider 12 — 12 — Other 8 9 2 — Total noncurrent regulatory assets $ 1,525 $ 1,504 $ 738 $ 709 PPL PPL Electric September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 35 $ 34 $ 35 $ 34 Transmission service charge 2 9 2 9 Environmental cost recovery 22 1 — — Universal service rider 23 26 23 26 Transmission formula rate 8 9 8 9 Fuel adjustment clause 7 3 — — TCJA customer refund (c) 26 — — — Storm damage expense rider 4 8 4 8 Other 9 5 — — Total current regulatory liabilities $ 136 $ 95 $ 72 $ 86 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 678 $ 677 $ — $ — Power purchase agreement - OVEC (d) 62 68 — — Net deferred taxes (e) 1,846 1,853 642 668 Defined benefit plans 33 27 — — Terminated interest rate swaps 72 74 — — TCJA customer refund (f) 41 — 41 — Other 7 5 3 — Total noncurrent regulatory liabilities $ 2,739 $ 2,704 $ 686 $ 668 LKE LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Assets: Plant outage costs $ 7 $ 3 $ 7 $ 3 $ — $ — Generation formula rate — 6 — — — 6 Gas supply clause 3 4 3 4 — — Other 1 5 1 5 — — Total current regulatory assets $ 11 $ 18 $ 11 $ 12 $ — $ 6 LKE LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, Noncurrent Regulatory Assets: Defined benefit plans $ 361 $ 376 $ 227 $ 234 $ 134 $ 142 Storm costs 23 33 12 18 11 15 Unamortized loss on debt 24 25 15 16 9 9 Interest rate swaps 18 26 18 26 — — Terminated interest rate swaps 88 92 52 54 36 38 AROs 267 234 74 61 193 173 Other 6 9 2 2 4 7 Total noncurrent regulatory assets $ 787 $ 795 $ 400 $ 411 $ 387 $ 384 LKE LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Environmental cost recovery $ 22 $ 1 $ 11 $ — $ 11 $ 1 Fuel adjustment clause 7 3 — — 7 3 Gas line tracker 2 3 2 3 — — TCJA customer refund (c) 26 — 12 — 14 — Other 7 2 1 — 6 2 Total current regulatory liabilities $ 64 $ 9 $ 26 $ 3 $ 38 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 678 $ 677 $ 280 $ 282 $ 398 395 Power purchase agreement - OVEC (d) 62 68 43 47 19 21 Net deferred taxes (e) 1,204 1,185 560 552 644 633 Defined benefit plans 33 27 — — 33 27 Terminated interest rate swaps 72 74 36 37 36 37 Other 4 5 1 1 3 4 Total noncurrent regulatory liabilities $ 2,053 $ 2,036 $ 920 $ 919 $ 1,133 $ 1,117 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b) Storm costs incurred in PPL Electric's territory from a March 2018 storm will be amortized from 2019 through 2021. (c) Relates to estimated amounts owed to LG&E and KU customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, effective January 1, 2018. Amounts owed will be distributed through the TCJA bill credit. (d) This liability was recorded as an offset to an intangible asset that was recorded at fair value upon the acquisition of LKE by PPL. (e) Primarily relates to excess deferred taxes recorded as a result of the TCJA, which reduced the U.S. federal corporate income tax rate effective January 1, 2018, requiring deferred tax balances and the associated regulatory liabilities to be remeasured as of December 31, 2017. LG&E and KU began distributing amounts through the TCJA bill credit effective April 1, 2018. (f) Relates to amounts owed to PPL Electric customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, for the period of January 1, 2018 through June 30, 2018 which is not yet reflected in distribution customer rates. The distribution method back to customers of this liability must be proposed to the PUC at the earlier of May 2021 or PPL Electric’s next rate case. Regulatory Matters Kentucky Activities (PPL, LKE, LG&E and KU) 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 , respectively, 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% , respectively, 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% . 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 to implement 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 reducing 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 March 26, 2018, LG&E and KU filed a petition for reconsideration and request for hearing with the KPSC, taking exception to the KPSC's modifications and the process, and also requested certain relief from implementing the amounts represented by the additional reductions until the matter is fully resolved. On March 28, 2018, the Office of the Attorney General filed a response to the petition and gave notice of its withdrawal from the settlement agreement. On March 28, 2018, the KPSC issued an Order granting LG&E's and KU's request for reconsideration and amending its March 20, 2018 Order by suspending the approved rates, allowing LG&E and KU, on an interim basis, to return savings related to the TCJA at the rates agreed to in the January 29, 2018 settlement. On September 28, 2018, the KPSC issued an Order on reconsideration, 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). LG&E and KU have been implementing interim partial rate reductions since April 2018, as authorized by the KPSC on March 28, 2018, and recording reserves up to the higher reduction amounts originally approved in the March 20, 2018 Order. The September 28, 2018 Order is not expected to have a material adverse impact on LG&E's and KU's financial condition or results of operations. Additionally, on January 8, 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. On March 22, 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. On May 8, 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 March 15, 2018, the FERC issued a Notice of Inquiry seeking information on whether and how it should address changes relating to accumulated deferred income taxes and bonus depreciation resulting from passage of the TCJA on FERC-jurisdictional rates. LG&E and KU have not made any submission in response to the Notice of Inquiry, but do not anticipate the impact of the TCJA related to their FERC-jurisdictional rates to be significant. Gas Franchise (LKE and LG&E) 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 franchise agreement with a 5 -year term (with renewal options). The franchise fee may be modified at Louisville/Jefferson County's election upon 60 days' notice. However, any franchise fee is capped at 3% of gross receipts for natural gas service within the franchise area. The agreement further provides that if the KPSC determines that the franchise fee should be recovered from LG&E's Louisville/Jefferson county customers in the franchise areas as a separate line item on their bill, the franchise fee will revert to zero . In August 2016, LG&E filed an application requesting the KPSC to review and rule upon the recoverability of the franchise fee. On March 14, 2018, the KPSC issued an Order authorizing the franchise fee to be recovered only from LG&E's Louisville/Jefferson County customers in the franchise area. As a result, the franchise fee will continue to be zero in accordance with the terms of the August 2016, 5 -year gas franchise agreement. (PPL and PPL Electric) Pennsylvania Activities TCJA Impact on PPL Electric Rates On February 12, 2018, the PUC issued a Secretarial Letter requesting certain information from regulated utilities and inviting comment from interested parties on potential revision to customer rates as a result of enactment of the TCJA. PPL Electric submitted its response to the Secretarial Letter on March 9, 2018. On March 15, 2018, the PUC issued a Temporary Rates Order to allow time to determine the manner in which rates could be adjusted in response to the TCJA. The PUC issued another Temporary Rates Order on May 17, 2018 to address the impact of the TCJA and indicated that utilities without a currently pending general rate proceeding would receive a utility specific order. The PUC issued an Order specific to PPL Electric on May 17, 2018 which required PPL Electric to file a tariff or tariff supplement by June 15, 2018 to establish (a) temporary rates to include a negative surcharge of 0.56% , which was based on PPL Electric's 2017 taxable income, to be effective July 1, 2018, and (b) to record a deferred regulatory liability to reflect the tax savings associated with the TCJA for the period January 1 through June 30, 2018. On June 8, 2018, PPL Electric submitted a petition to the PUC to increase the negative surcharge proposed in the May 17, 2018 Order from 0.56% to 7.05% to reflect the estimated 2018 tax savings associated with the TCJA. The PUC approved PPL Electric's petition on June 14, 2018 and PPL Electric filed a tariff on June 15, 2018 reflecting the increased negative surcharge. The estimated 2018 full year impact of the rate reduction is $72 million in PPL Electric's operating revenues, of which $39 million relates to the period January 1, 2018 through June 30, 2018 and was recorded as a noncurrent regulatory liability in the second quarter of 2018 to be distributed to customers pursuant to a future rate adjustment. The remaining $33 million is the estimated impact for the period July 1, 2018 through December 31, 2018 and is being passed back to customers through the negative surcharge which began on July 1, 2018. On March 15, 2018, the FERC issued a Notice of Inquiry seeking information on whether and how it should address changes to FERC-jurisdictional rates relating to accumulated deferred income taxes and bonus depreciation resulting from passage of the TCJA. On March 16, 2018, PPL Electric filed a waiver request, pursuant to Rule 207(a)(5) of the Rules of Practice and Procedure of the FERC, to accelerate incorporation of the changes to the federal corporate income tax rate in its transmission formula rate commencing on June 1, 2018 rather than allowing the TCJA tax rate reduction to be initially incorporated in PPL Electric's June 1, 2019 transmission formula rate. The waiver was approved on April 23, 2018 and PPL Electric submitted its transmission formula rate, reflecting the TCJA rate reduction, on April 27, 2018. In addition, on May 21, 2018, PPL Electric, as part of a PJM Transmission Owners joint filing, submitted comments in response to the FERC's March 15, 2018 Notice of Inquiry. The filing requested guidance on how the reduction in accumulated deferred income taxes, resulting from the TCJA reduced federal corporate income tax rate, should be treated for ratemaking purposes. PPL Electric is currently awaiting FERC's decision on this matter. The changes, related to accumulated deferred income taxes impacting the transmission formula rate revenues, have not been significant since the new rate went into effect on June 1, 2018. Federal Matters (PPL, LKE, LG&E and KU) FERC Transmission Rate Filing On August 3, 2018, LG&E and KU submitted an application to the FERC requesting elimination of certain on-going credits to a sub-set of transmission customers relating to the 1998 merger of LG&E’s and KU’s parent entities and the 2006 withdrawal of LG&E and KU from the Midcontinent Independent System Operator, Inc. (MISO), a regional transmission operator and energy market. The application seeks termination of LG&E’s and KU’s commitment to provide mitigation for certain horizontal market power concerns arising out of the 1998 merger for certain transmission service between MISO and LG&E and KU. The affected transmission customers are a limited number of municipal entities in Kentucky or Tennessee. The amounts at issue are generally waivers or credits for either LG&E and KU or for MISO transmission charges depending upon the direction of transmission service incurred by the municipalities. LG&E and KU estimate that such charges may average approximately $22 million annually, depending upon actual transmission customer and market volumes, structures and prices, with such charges allocated according to LG&E's and KU’s respective transmission system ownership ratio. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate. LG&E and KU currently receive recovery of such expenses in other rate mechanisms. LG&E and KU cannot predict the outcome of the proceeding, including any effects on their financial condition or results of operations. Transmission Customer Complaint On September 21, 2018, a transmission customer filed a complaint with the FERC against LG&E and KU alleging LG&E and KU have violated and continue to violate their obligations under an existing rate schedule to credit this customer for certain transmission charges from MISO. On October 11, 2018, LG&E and KU filed an answer to the complaint arguing such MISO transmission transactions are not covered by the rate schedule, and the amounts in question are not eligible for credits. LG&E and KU cannot predict the outcome of the proceeding, but believe that any potential required credits would be subject to rate recovery. Other Purchase of Receivables Program (PPL and PPL Electric) In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three and nine months ended September 30, 2018 , PPL Electric purchased $334 million and $1 billion of accounts receivable from alternate suppliers. During the three and nine months ended September 30, 2017 , PPL Electric purchased $324 million and $968 million of accounts receivable from alternate suppliers.

Financing Activities

Financing Activities	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Financing Activities	8. Financing Activities Credit Arrangements and Short-term Debt (All Registrants) The Registrants maintain credit facilities to enhance liquidity, provide credit support and act as 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 agreement, which are reflected in "Long-term debt" on the Balance Sheets. The following credit facilities were in place at: September 30, 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) Jan. 2023 £ 210 £ 154 £ — £ 54 £ 148 £ — Term Loan Facility (b) Dec. 2018 130 130 — — — — WPD (South West) Syndicated Credit Facility July 2021 245 — — 245 — — WPD (East Midlands) Syndicated Credit Facility (c) July 2021 300 93 — 207 180 — WPD (West Midlands) Syndicated Credit Facility (d) July 2021 300 50 — 250 120 — Uncommitted Credit Facilities 130 — 4 126 — 4 Total U.K. Credit Facilities (e) £ 1,315 £ 427 £ 4 £ 882 £ 448 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility Jan. 2023 $ 950 $ — $ 691 $ 259 $ — $ 230 Syndicated Credit Facility Nov. 2018 300 — — 300 — — Bilateral Credit Facility Mar. 2019 100 — 20 80 — 18 Total PPL Capital Funding Credit Facilities $ 1,350 $ — $ 711 $ 639 $ — $ 248 PPL Electric Syndicated Credit Facility Jan. 2023 $ 650 $ — $ 1 $ 649 $ — $ 1 LKE Syndicated Credit Facility Oct. 2018 $ 75 $ — $ — $ 75 $ — $ — LG&E Syndicated Credit Facility Jan. 2023 $ 500 $ — $ 176 $ 324 $ — $ 199 Term Loan Credit Facility Oct. 2019 200 200 — — 100 — Total LG&E Credit Facilities $ 700 $ 200 $ 176 $ 324 $ 100 $ 199 September 30, 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 KU Syndicated Credit Facility Jan. 2023 $ 400 $ — $ 128 $ 272 $ — $ 45 Letter of Credit Facility Oct. 2020 198 — 198 — — 198 Total KU Credit Facilities $ 598 $ — $ 326 $ 272 $ — $ 243 (a) The amounts borrowed at September 30, 2018 and December 31, 2017 were USD-denominated borrowings of $200 million for both periods, which bore interest at 2.90% and 2.17% . The unused capacity reflects the amount borrowed in GBP of £156 million as of the date borrowed. (b) The amount borrowed at September 30, 2018 was a GBP-denominated borrowing which equated to $168 million and bore interest at 1.97% . (c) The amounts borrowed at September 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $121 million and $244 million and bore interest at 1.09% and 0.89% . (d) The amounts borrowed at September 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $65 million and $162 million and bore interest at 1.12% and 0.89% . (e) At September 30, 2018 , the unused capacity under the U.K. credit facilities was $1.1 billion . In October 2018, LKE's $75 million credit facility expired. LKE increased its revolving line of credit with a PPL Energy Funding subsidiary by $75 million to a limit of $375 million . See Note 11 for additional information. 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 Syndicated Credit Facility. The following commercial paper programs were in place at: September 30, 2018 December 31, 2017 Weighted - Average Interest Rate Capacity Commercial Paper Issuances Unused Capacity Weighted - Average Interest Rate Commercial Paper Issuances PPL Capital Funding 2.38% $ 1,000 $ 691 $ 309 1.64% $ 230 PPL Electric 650 — 650 — LG&E 2.34% 350 176 174 1.83% 199 KU 2.34% 350 128 222 1.97% 45 Total $ 2,350 $ 995 $ 1,355 $ 474 (PPL Electric, LKE, and LG&E) See Note 11 for discussion of intercompany borrowings. Long-term Debt (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 Notes 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 will be 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 11 for additional information related to intercompany borrowings. (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 nine months ended September 30, 2018 . Distributions In August 2018, PPL declared a quarterly common stock dividend, payable October 1, 2018 , of 41.0 cents per share (equivalent to $1.64 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.

Defined Benefits

Defined Benefits	9 Months Ended
	Sep. 30, 2018
Retirement Benefits [Abstract]
Defined Benefits	9. Defined Benefits (PPL, LKE and LG&E) Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense and regulatory assets, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE, and LG&E for the periods ended September 30 : Pension Benefits Three Months Nine Months U.S. U.K. U.S. U.K. 2018 2017 2018 2017 2018 2017 2018 2017 PPL Service cost $ 15 $ 17 $ 21 $ 20 $ 46 $ 49 $ 63 $ 57 Interest cost 39 42 46 45 117 126 140 132 Expected return on plan assets (62 ) (58 ) (145 ) (130 ) (186 ) (173 ) (445 ) (382 ) Amortization of: Prior service cost 2 2 — — 7 7 — — Actuarial loss 22 18 37 36 63 52 114 107 Net periodic defined benefit costs (credits) before settlements and special termination benefits 16 21 (41 ) (29 ) 47 61 (128 ) (86 ) Settlements (a) — 1 — — — 1 — — Special termination benefits (b) — — — — — 1 — — Net periodic defined benefit costs (credits) $ 16 $ 22 $ (41 ) $ (29 ) $ 47 $ 63 $ (128 ) $ (86 ) (a) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 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. (b) Enhanced pension benefits offered to certain PPL Electric bargaining unit employees under a one-time voluntary retirement window offered as part of the new five year IBEW contract ratified in March 2017. Pension Benefits Three Months Nine Months 2018 2017 2018 2017 LKE Service cost $ 6 $ 6 $ 18 $ 18 Interest cost 16 17 48 51 Expected return on plan assets (25 ) (23 ) (76 ) (69 ) Amortization of: Pension Benefits Three Months Nine Months 2018 2017 2018 2017 Prior service cost 3 2 7 6 Actuarial loss (a) 8 8 26 23 Net periodic defined benefit costs (b) $ 8 $ 10 $ 23 $ 29 (a) As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LKE's accounting policy and actuarial loss calculated using a 15 -year amortization period was $2 million and $8 million for the three and nine months ended September 30, 2018 and $3 million and $8 million for the three and nine months ended September 30, 2017. This difference is recorded as a regulatory asset. (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 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. Pension Benefits Three Months Nine Months 2018 2017 2018 2017 LG&E Service cost $ — $ — $ 1 $ 1 Interest cost 3 3 9 9 Expected return on plan assets (6 ) (5 ) (17 ) (16 ) Amortization of: Prior service cost 1 1 4 3 Actuarial loss (a) 2 3 5 7 Net periodic defined benefit costs (b) $ — $ 2 $ 2 $ 4 (a) As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LG&E's accounting policy and actuarial loss calculated using a 15 -year amortization period was $1 million for the nine months ended September 30, 2018 and $1 million and $3 million for the three and nine months ended September 30, 2017. This difference is recorded as a regulatory asset. (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 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. Other Postretirement Benefits Three Months Nine Months 2018 2017 2018 2017 PPL Service cost $ 1 $ 2 $ 5 $ 6 Interest cost 5 5 15 17 Expected return on plan assets (4 ) (6 ) (17 ) (17 ) Amortization of prior service cost — — — (1 ) Amortization of actuarial loss — 1 — 1 Net periodic defined benefit costs $ 2 $ 2 $ 3 $ 6 LKE Service cost $ 1 $ 1 $ 3 $ 3 Interest cost 2 2 6 6 Expected return on plan assets (2 ) (2 ) (6 ) (5 ) Amortization of: Prior service cost — 1 1 1 Actuarial gain — — (1 ) — Net periodic defined benefit costs $ 1 $ 2 $ 3 $ 5 (PPL Electric, LG&E and KU) In addition to the specific plan it sponsors, LG&E is allocated costs of defined benefit plans sponsored by LKE. PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric is allocated costs of defined benefit plans sponsored by PPL Services and KU is allocated costs of defined benefit plans sponsored by LKE. LG&E and KU are also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 11 for additional information on costs allocated to LG&E and KU from LKS. These allocations are based on participation in those plans, which management believes are reasonable. For the periods ended September 30 , PPL Services allocated the following net periodic defined benefit costs to PPL Electric, and LKE allocated the following net periodic defined benefit costs to LG&E and KU: Three Months Nine Months 2018 2017 2018 2017 PPL Electric $ 5 $ 6 $ 12 $ 19 LG&E 1 3 5 8 KU 1 2 3 7 (All Registrants) The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the Statements of Income. See Note 12 for additional information.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	10. Commitments and Contingencies 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. Claim by Former Affiliate (PPL) On October 29, 2018, Talen Montana, LLC ("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, County of Lewis & Clark. On the same day, Talen Montana Retirement Plan and certain other creditors of Talen Montana filed a complaint against PPL and certain of its affiliates and current and former officers and directors in the Sixteenth Judicial District of the State of Montana, Rosebud County. Talen Montana became a wholly owned subsidiary of Talen Energy as a result of the June 2015 spinoff of PPL Energy Supply. Talen Energy has owned and operated Talen Montana's business since the spinoff. At the time of the spinoff, affiliates of Riverstone acquired a 35% ownership interest in Talen Energy. See Note 8 to the Consolidated Financial Statements in PPL's 2017 Form 10-K for a description of the 2015 spinoff of PPL Energy Supply. Riverstone subsequently acquired the remaining interests in Talen Energy in 2016. The complaints allege that in 2014 PPL and its officers and directors improperly distributed $733 million of the proceeds from the November 2014 sale of Talen Montana's (then PPL Montana's) hydroelectric generating facilities to PPL's subsidiaries. The complaints also allege that PPL and certain current and former officers and directors of PPL and its subsidiaries breached their fiduciary duties in connection with the 2014 distribution. PPL believes that the referenced 2014 distribution of proceeds was made in compliance with all applicable laws and that PPL Montana was solvent upon the 2014 distribution. Additionally, in the agreements entered into with respect to the spinoff, affiliates of Talen Energy and Riverstone definitively agreed that PPL was entitled to retain the proceeds from the November 2014 sale of PPL Montana's hydroelectric generating facilities. PPL believes that it has good and meritorious defenses to these claims and fully plans to vigorously defend against these actions. 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. Cane Run Environmental Claims (PPL, LKE and LG&E) In December 2013, six residents, on behalf of themselves and others similarly situated, filed a class action complaint against LG&E and PPL in the U.S. District Court for the Western District of Kentucky (U.S. District Court) alleging violations of the Clean Air Act, RCRA, and common law claims of nuisance, trespass and negligence. 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 occur in late 2018 or 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. E.W. Brown Environmental Claims ( PPL, LKE and KU) 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. The case has been briefed and oral argument was presented on August 2, 2018. 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. 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 late 2017 through mid-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. Regulatory Issues ( All Registrants) 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 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. 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 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 2015 EPA Rules). On August 21, 2018, the EPA proposed the Affordable Clean Energy Act (ACE) Rule as a replacement for the 2015 EPA Rules pertaining to existing sources. The EPA took this action following legal challenges to the 2015 EPA Rules, a stay of those rules by the U.S. Supreme Court, a March 2017 Executive Order requiring the EPA to review those rules and EPA’s October 2017 proposal to rescind the rules. 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 2015 EPA Rules, 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 December 2018. 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 in late 2018. 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 impacts as a result of the judicial ruling. Separately, in December 2016, federal legislation was enacted that authorized the EPA to approve equally protective state programs that would operate in lieu of the CCR rule. The Kentucky Energy and Environmental Cabinet has indicated it may propose rules under such authority in the future. LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. On January 26, 2018, KU filed an application requesting a CPCN and approval of amendments to the second phase of its compliance plan for the landfill at the E.W. Brown station. On July 9, 2018, the KPSC granted approval to KU for amendments to the second phase of its compliance plan for the landfill at the E.W. Brown station. In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 16 below and Note 19 in the Registrants' 2017 Form 10-K for additional information. Further changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are subject to rate recovery. Clean Water Act Regulations under the federal Clean Water Act dictate permitting and mitigation requirements for facilities and construction projects in the United States. Many of those requirements relate to power plant operations, including requirements related to the treatment of pollutants in effluents prior to discharge, the temperature of effluent discharges and the location, design and construction of cooling water intake structures at generating facilities, standards intended to protect aquatic organisms that become trapped at or pulled through cooling water intake structures at generating facilities. The requirements could impose significant costs for LG&E and KU, which are subject to rate recovery. Litigation is currently pending in various courts relating to whether Clean Water Act jurisdiction covers discharges of contaminated groundwater that reach surface water via a direct hydrologic connection. Courts in different jurisdictions have come to contrary conclusions in the past. On February 20, 2018, the EPA issued a notice requesting comment on the scope of discharges subject to regulation under the Clean Water Act. Specifically, the EPA seeks comments on whether Clean Water Act jurisdiction should cover discharges to groundwater that reach surface water via a direct hydrologic connection. Extending Clean Water Act jurisdiction to such discharges could potentially subject certain releases from CCR impoundments to additional permitting and remediation requirements. PPL, LKE, LG&E and KU are unable to predict the future regulatory developments or potential impacts on current LG&E and KU compliance plans. ELGs In September 2015, the EPA released its final ELGs for wastewater discharge permits for new and existing steam electric generating facilities. The rule provides strict technology-based discharge limitations for control of pollutants in scrubber wastewater, fly ash and bottom ash transport water, mercury control wastewater, gasification wastewater and combustion residual leachate. The new guidelines require deployment of additional control technologies providing physical, chemical and biological treatment of wastewaters. The guidelines also mandate operational changes including "no discharge" requirements for fly ash and bottom ash transport waters and mercury control wastewaters. The implementation date for individual generating stations will be determined by the states on a case-by-case basis according to criteria provided by the EPA. Industry groups, environmental groups, individual companies and others have filed legal challenges to the final rule, which have been consolidated before the U.S. Court of Appeals for the Fifth Circuit. In April 2017, the EPA announced that it would grant petitions for reconsideration of the rule. In September 2017, the EPA published in the Federal Register a proposed rule that would postpone the compliance date for requirements relating to bottom ash transport waters and scrubber wastewaters discharge limits. The EPA expects to complete its reconsideration of best available technology standards by the fall of 2020. Upon completion of the ongoing regulatory proceedings, the rule will be implemented by the states in the course of their normal permitting activities. LG&E and KU are developing compliance strategies and schedules. PPL, LKE, LG&E and KU are unable to predict the outcome of the EPA's pending reconsideration of the rule or fully estimate compliance costs or timing. Additionally, certain aspects of these compliance plans and estimates relate to developments in state water quality standards, which are separate from the ELG rule or its implementation. Costs to comply with ELGs or other discharge limits, which are expected to be significant, are subject to rate recovery. Seepages and Groundwater Infiltration In addition to the actions described above, LG&E and KU have completed, or are completing, assessments of seepages or groundwater infiltration at various facilities and have completed, or are working with agencies to implement, further testing, monitoring or abatement measures, where applicable. Depending on the circumstances in each case, certain costs, which may be subject to rate recovery, could be significant. LG&E and KU cannot currently estimate a possible loss or range of possible losses related to this matter. (All Registrants) Other Issues In June 2016, the "Frank Lautenberg Chemical Safety Act" took effect as an amendment to the Toxic Substance Control Act (TSCA). The Act made no changes to the pre-existing TSCA rules as it pertains to polychlorinated biphenyls (PCB). The EPA continues to reassess its PCB regulations as part of the 2010 Advanced Notice of Proposed Rulemaking (ANPRM). The EPA's ANPRM rulemaking is to occur in two phases. Only the second part of the rule is applicable to PPL operations. This part of the rule relates to the use of PCBs in electrical equipment and natural gas pipelines, as well as continued use of PCB-contaminated porous surfaces. Although the first rulemaking will not directly affect the Registrants' operations, it may indicate certain approaches or principles to occur in the later rulemaking which may affect Registrants' facilities in the United States, including phase-out of some or all equipment containing PCBs. Should such a phase-out be required, the costs, which are subject to rate recovery, could be significant. Currently, the EPA is planning to undertake the second phase of the rulemaking later in 2018. Superfund and Other Remediation PPL Electric, LG&E and KU are potentially responsible for investigating, responding to agency inquiries, implementing various preventative measures, and/or remediating contamination under programs other than those described in the sections above. These include a number of former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operate

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2018
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, 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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134 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 September 30, 2018 was $650 million . No balance was outstanding at September 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread. (LKE) LKE maintains a $300 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 a limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At September 30, 2018 and December 31, 2017 , $80 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at September 30, 2018 and December 31, 2017 were 3.61% and 2.87% . 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 September 30, 2018 and December 31, 2017 . The interest rate on the loan is based on the PPL affiliates credit rating and 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 September 30, 2018 and December 31, 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $4 million and $11 million for the three and nine months ending September 30, 2018 and 2017. 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 September 30, 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 $3 million and $4 million for the three and nine months ending September 30, 2018. Other (PPL Electric, LG&E and KU) See Note 9 for discussions regarding intercompany allocations associated with defined benefits. See Note 10 for discussions regarding separation benefits.
LG And E And KU Energy LLC [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, 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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134 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 September 30, 2018 was $650 million . No balance was outstanding at September 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread. (LKE) LKE maintains a $300 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 a limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At September 30, 2018 and December 31, 2017 , $80 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at September 30, 2018 and December 31, 2017 were 3.61% and 2.87% . 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 September 30, 2018 and December 31, 2017 . The interest rate on the loan is based on the PPL affiliates credit rating and 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 September 30, 2018 and December 31, 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $4 million and $11 million for the three and nine months ending September 30, 2018 and 2017. 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 September 30, 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 $3 million and $4 million for the three and nine months ending September 30, 2018. Other (PPL Electric, LG&E and KU) See Note 9 for discussions regarding intercompany allocations associated with defined benefits. See Note 10 for discussions regarding separation benefits.
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, 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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134 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 September 30, 2018 was $650 million . No balance was outstanding at September 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread. (LKE) LKE maintains a $300 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 a limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At September 30, 2018 and December 31, 2017 , $80 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at September 30, 2018 and December 31, 2017 were 3.61% and 2.87% . 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 September 30, 2018 and December 31, 2017 . The interest rate on the loan is based on the PPL affiliates credit rating and 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 September 30, 2018 and December 31, 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $4 million and $11 million for the three and nine months ending September 30, 2018 and 2017. 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 September 30, 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 $3 million and $4 million for the three and nine months ending September 30, 2018. Other (PPL Electric, LG&E and KU) See Note 9 for discussions regarding intercompany allocations associated with defined benefits. See Note 10 for discussions regarding separation benefits.
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, 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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134 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 September 30, 2018 was $650 million . No balance was outstanding at September 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread. (LKE) LKE maintains a $300 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 a limit of $375 million . The interest rates on borrowings are equal to one-month LIBOR plus a spread. At September 30, 2018 and December 31, 2017 , $80 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at September 30, 2018 and December 31, 2017 were 3.61% and 2.87% . 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 September 30, 2018 and December 31, 2017 . The interest rate on the loan is based on the PPL affiliates credit rating and 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 September 30, 2018 and December 31, 2017 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $4 million and $11 million for the three and nine months ending September 30, 2018 and 2017. 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 September 30, 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 $3 million and $4 million for the three and nine months ending September 30, 2018. Other (PPL Electric, LG&E and KU) See Note 9 for discussions regarding intercompany allocations associated with defined benefits. See Note 10 for discussions regarding separation benefits.

Other Income (Expense) - net

Other Income (Expense) - net	9 Months Ended
	Sep. 30, 2018
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	12. Other Income (Expense) - net (PPL) The details of "Other Income (Expense) - net" for the periods ended September 30 , were: Three Months Nine Months 2018 2017 2018 2017 Other Income Economic foreign currency exchange contracts (Note 14) $ 40 $ (81 ) $ 92 $ (237 ) Defined benefit plans - non-service credits (Note 9) 61 41 195 123 Interest income 3 1 5 2 AFUDC - equity component 5 5 15 11 Miscellaneous 2 2 3 11 Total Other Income 111 (32 ) 310 (90 ) Other Expense Charitable contributions 1 1 6 6 Miscellaneous 4 2 7 16 Total Other Expense 5 3 13 22 Other Income (Expense) - net $ 106 $ (35 ) $ 297 $ (112 ) (PPL Electric) The details of "Other Income (Expense) - net" for the periods ended September 30 , were: Three Months Nine Months 2018 2017 2018 2017 Other Income AFUDC - equity component $ 5 $ 5 $ 15 $ 11 Defined benefit plans - non-service credits (Note 9) 1 — 4 — Miscellaneous — — 1 — Total Other Income 6 5 20 11 Other Expense Charitable contributions 1 1 2 2 Miscellaneous — — — 1 Total Other Expense 1 1 2 3 Other Income (Expense) - net $ 5 $ 4 $ 18 $ 8
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	12. Other Income (Expense) - net (PPL) The details of "Other Income (Expense) - net" for the periods ended September 30 , were: Three Months Nine Months 2018 2017 2018 2017 Other Income Economic foreign currency exchange contracts (Note 14) $ 40 $ (81 ) $ 92 $ (237 ) Defined benefit plans - non-service credits (Note 9) 61 41 195 123 Interest income 3 1 5 2 AFUDC - equity component 5 5 15 11 Miscellaneous 2 2 3 11 Total Other Income 111 (32 ) 310 (90 ) Other Expense Charitable contributions 1 1 6 6 Miscellaneous 4 2 7 16 Total Other Expense 5 3 13 22 Other Income (Expense) - net $ 106 $ (35 ) $ 297 $ (112 ) (PPL Electric) The details of "Other Income (Expense) - net" for the periods ended September 30 , were: Three Months Nine Months 2018 2017 2018 2017 Other Income AFUDC - equity component $ 5 $ 5 $ 15 $ 11 Defined benefit plans - non-service credits (Note 9) 1 — 4 — Miscellaneous — — 1 — Total Other Income 6 5 20 11 Other Expense Charitable contributions 1 1 2 2 Miscellaneous — — — 1 Total Other Expense 1 1 2 3 Other Income (Expense) - net $ 5 $ 4 $ 18 $ 8

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	13. Fair Value Measurements (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. Transfers between levels are recognized at end-of-reporting-period values. During the three and nine months ended September 30, 2018 and 2017 , there were no transfers between Level 1 and Level 2. See Note 1 in each Registrant's 2017 Form 10-K for information on the levels in the fair value hierarchy. Recurring Fair Value Measurements The assets and liabilities measured at fair value were: September 30, 2018 December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 842 $ 842 $ — $ — $ 485 $ 485 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 26 26 — — Special use funds (a) 63 63 — — — — — — Price risk management assets (b): Foreign currency contracts 174 — 174 — 163 — 163 — Cross-currency swaps 123 — 123 — 101 — 101 — Total price risk management assets 297 — 297 — 264 — 264 — Total assets $ 1,224 $ 927 $ 297 $ — $ 775 $ 511 $ 264 $ — September 30, 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 $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — Foreign currency contracts 30 — 30 — 148 — 148 — Total price risk management liabilities $ 49 $ — $ 49 $ — $ 174 $ — $ 174 $ — PPL Electric Assets Cash and cash equivalents $ 414 $ 414 $ — $ — $ 49 $ 49 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 416 $ 416 $ — $ — $ 51 $ 51 $ — $ — LKE Assets Cash and cash equivalents $ 29 $ 29 $ — $ — $ 30 $ 30 $ — $ — Total assets $ 29 $ 29 $ — $ — $ 30 $ 30 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — LG&E Assets Cash and cash equivalents $ 11 $ 11 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 11 $ 11 $ — $ — $ 15 $ 15 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — KU Assets Cash and cash equivalents $ 18 $ 18 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 18 $ 18 $ — $ — $ 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 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. September 30, 2018 December 31, 2017 Carrying Fair Value Carrying Fair Value PPL $ 20,254 $ 23,023 $ 20,195 $ 23,783 PPL Electric 3,693 3,899 3,298 3,769 LKE 5,501 5,783 5,159 5,670 LG&E 1,808 1,879 1,709 1,865 KU 2,320 2,467 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	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	14. 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 in PPL's 2017 Form 10-K 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 $25 million obligation to return cash collateral under master netting arrangements at September 30, 2018 and a $20 million obligation to return cash collateral under master netting arrangements at December 31, 2017 . PPL had no obligation to post cash collateral under master netting arrangements at September 30, 2018 and December 31, 2017 . LKE, LG&E and KU had no obligation to return cash collateral under master netting arrangements at September 30, 2018 and December 31, 2017 . LKE, LG&E and KU had no cash collateral posted under master netting arrangements at September 30, 2018 and December 31, 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. At September 30, 2018 , PPL held an aggregate notional value in interest rate swap contracts of £75 million (approximately $97 million based on spot rates) that mature in 2026 to hedge the interest payments of WPD plc's October 2018 debt issuance. For the three and nine months ended September 30, 2018 and 2017 , PPL had no hedge ineffectiveness associated with interest rate derivatives. At September 30, 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 the three and nine months ended September 30, 2018 and 2017 , 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 the three and nine months ended September 30, 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and nine months ended September 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At September 30, 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. At September 30, 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 September 30, 2018 . At September 30, 2018 and December 31, 2017 , PPL had $30 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 September 30, 2018 , the total exposure hedged by PPL was approximately £1.8 billion (approximately $2.5 billion based on contracted rates). These contracts have termination dates ranging from October 2018 through October 2020 . Accounting and Reporting (All Registrants) All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNS is elected. NPNS contracts for PPL and PPL Electric include certain full-requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 7 for amounts recorded in regulatory assets and regulatory liabilities at September 30, 2018 and December 31, 2017 . See Note 1 in each Registrant's 2017 Form 10-K 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. September 30, 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) 5 — — — 4 — — — Foreign currency contracts — — 86 22 — — 45 67 Total current 5 — 86 26 4 — 45 71 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 15 — — — 22 Cross-currency swaps (b) 118 — — — 97 — — — Foreign currency contracts — — 88 8 — — 118 81 Total noncurrent 118 — 88 23 97 — 118 103 Total derivatives $ 123 $ — $ 174 $ 49 $ 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 for the periods ended September 30, 2018 . Three Months Nine Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Nine Months Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ (2 ) $ — $ (6 ) $ — Cross-currency swaps 27 26 Interest expense 1 — 1 — Other income (expense) - net 18 — 30 — Total $ 27 $ 26 $ 17 $ — $ 25 $ — Net Investment Hedges: Foreign currency contracts $ — $ 11 Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Nine Months Foreign currency contracts Other income (expense) - net $ 40 $ 92 Interest rate swaps Interest expense (1 ) (4 ) Total $ 39 $ 88 Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 2 $ 7 The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the periods ended September 30, 2017 . Three Months Nine Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Nine Months Cash Flow Hedges: Interest rate swaps $ — $ (2 ) Interest expense $ (2 ) $ — $ (6 ) $ (1 ) Cross-currency swaps 1 (34 ) Interest expense 1 — 1 — Other income (expense) - net 2 — (24 ) — Total $ 1 $ (36 ) $ 1 $ — $ (29 ) $ (1 ) Net Investment Hedges: Foreign currency contracts $ 1 $ 1 Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Nine Months Foreign currency contracts Other income (expense) - net $ (81 ) $ (237 ) Interest rate swaps Interest expense (1 ) (4 ) Total $ (82 ) $ (241 ) Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 1 $ 2 (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. September 30, 2018 December 31, 2017 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 4 $ — $ 4 Total current — 4 — 4 September 30, 2018 December 31, 2017 Assets Liabilities Assets Liabilities Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 15 — 22 Total noncurrent — 15 — 22 Total derivatives $ — $ 19 $ — $ 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 for the periods ended September 30, 2018 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ (1 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 2 $ 7 The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, 2017 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ (1 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 1 $ 2 (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 September 30, 2018 Treasury Derivatives PPL $ 297 $ 28 $ 25 $ 244 $ 49 $ 28 $ — $ 21 LKE — — — — 19 — — 19 LG&E — — — — 19 — — 19 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 September 30, 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 $ 8 $ 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) 8 6 6 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210
LG And E And KU Energy LLC [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210
Louisville Gas And Electric Co [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210
Kentucky Utilities Co [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	16. Accumulated Other Comprehensive Income (Loss) (PPL and LKE) The after-tax changes in AOCI by component for the periods ended September 30 were as follows. Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL June 30, 2018 $ (1,223 ) $ (21 ) $ — $ (7 ) $ (2,244 ) $ (3,495 ) Amounts arising during the period (187 ) 22 — — (8 ) (173 ) Reclassifications from AOCI — (14 ) — — 34 20 Net OCI during the period (187 ) 8 — — 26 (153 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Amounts arising during the period (321 ) 21 — (1 ) (9 ) (310 ) Reclassifications from AOCI — (21 ) — 1 104 84 Net OCI during the period (321 ) — — — 95 (226 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) Amounts arising during the period (12 ) 1 — — (3 ) (14 ) Reclassifications from AOCI — — — — 34 34 Net OCI during the period (12 ) 1 — — 31 20 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 195 (29 ) — — (14 ) 152 Reclassifications from AOCI — 24 1 1 97 123 Net OCI during the period 195 (5 ) 1 1 83 275 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) LKE June 30, 2018 $ — $ (8 ) $ (78 ) $ (86 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 1 2 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) December 31, 2017 $ — $ (9 ) $ (79 ) $ (88 ) Reclassifications from AOCI — 2 2 4 Net OCI during the period — 2 2 4 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) Amounts arising during the period — — (1 ) (1 ) Reclassifications from AOCI — — 1 1 Net OCI during the period — — — — September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (12 ) (12 ) Reclassifications from AOCI 1 1 3 5 Net OCI during the period 1 1 (9 ) (7 ) September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) (PPL) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended September 30 . Three Months Nine Months Affected Line Item on the Details about AOCI 2018 2017 2018 2017 Statements of Income Qualifying derivatives Interest rate swaps $ (2 ) $ (2 ) $ (6 ) $ (7 ) Interest Expense Cross-currency swaps 18 2 30 (24 ) Other Income (Expense) - net 1 1 1 1 Interest Expense Total Pre-tax 17 1 25 (30 ) Income Taxes (3 ) (1 ) (4 ) 6 Total After-tax 14 — 21 (24 ) Three Months Nine Months Affected Line Item on the Details about AOCI 2018 2017 2018 2017 Statements of Income Equity investees' AOCI — — — (1 ) Other Income (Expense) - net Total Pre-tax — — — (1 ) Income Taxes — — — — Total After-tax — — — (1 ) Defined benefit plans Prior service costs (a) (1 ) (1 ) (2 ) (2 ) Net actuarial loss (a) (42 ) (44 ) (130 ) (125 ) Total Pre-tax (43 ) (45 ) (132 ) (127 ) Income Taxes 9 11 27 29 Total After-tax (34 ) (34 ) (105 ) (98 ) Total reclassifications during the period $ (20 ) $ (34 ) $ (84 ) $ (123 ) (a) These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	16. Accumulated Other Comprehensive Income (Loss) (PPL and LKE) The after-tax changes in AOCI by component for the periods ended September 30 were as follows. Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL June 30, 2018 $ (1,223 ) $ (21 ) $ — $ (7 ) $ (2,244 ) $ (3,495 ) Amounts arising during the period (187 ) 22 — — (8 ) (173 ) Reclassifications from AOCI — (14 ) — — 34 20 Net OCI during the period (187 ) 8 — — 26 (153 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Amounts arising during the period (321 ) 21 — (1 ) (9 ) (310 ) Reclassifications from AOCI — (21 ) — 1 104 84 Net OCI during the period (321 ) — — — 95 (226 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) Amounts arising during the period (12 ) 1 — — (3 ) (14 ) Reclassifications from AOCI — — — — 34 34 Net OCI during the period (12 ) 1 — — 31 20 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 195 (29 ) — — (14 ) 152 Reclassifications from AOCI — 24 1 1 97 123 Net OCI during the period 195 (5 ) 1 1 83 275 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) LKE June 30, 2018 $ — $ (8 ) $ (78 ) $ (86 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 1 2 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) December 31, 2017 $ — $ (9 ) $ (79 ) $ (88 ) Reclassifications from AOCI — 2 2 4 Net OCI during the period — 2 2 4 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) Amounts arising during the period — — (1 ) (1 ) Reclassifications from AOCI — — 1 1 Net OCI during the period — — — — September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (12 ) (12 ) Reclassifications from AOCI 1 1 3 5 Net OCI during the period 1 1 (9 ) (7 ) September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) (PPL) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended September 30 . Three Months Nine Months Affected Line Item on the Details about AOCI 2018 2017 2018 2017 Statements of Income Qualifying derivatives Interest rate swaps $ (2 ) $ (2 ) $ (6 ) $ (7 ) Interest Expense Cross-currency swaps 18 2 30 (24 ) Other Income (Expense) - net 1 1 1 1 Interest Expense Total Pre-tax 17 1 25 (30 ) Income Taxes (3 ) (1 ) (4 ) 6 Total After-tax 14 — 21 (24 ) Three Months Nine Months Affected Line Item on the Details about AOCI 2018 2017 2018 2017 Statements of Income Equity investees' AOCI — — — (1 ) Other Income (Expense) - net Total Pre-tax — — — (1 ) Income Taxes — — — — Total After-tax — — — (1 ) Defined benefit plans Prior service costs (a) (1 ) (1 ) (2 ) (2 ) Net actuarial loss (a) (42 ) (44 ) (130 ) (125 ) Total Pre-tax (43 ) (45 ) (132 ) (127 ) Income Taxes 9 11 27 29 Total After-tax (34 ) (34 ) (105 ) (98 ) Total reclassifications during the period $ (20 ) $ (34 ) $ (84 ) $ (123 ) (a) These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Description of New Accounting Pronouncements Not yet Adopted [Text Block]	17. 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. 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 standard is effective for public business entities for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted. The new standard must be adopted using a modified retrospective transition method with transition applied either retrospectively to each prior reporting period presented in the financial statements or as of the beginning of the period of adoption. The standard also provides for certain practical expedients. One of these practical expedients allows entities to elect to (1) not reassess whether existing contracts contain leases, (2) carryforward the existing lease classification, and (3) not reassess initial direct costs associated with existing leases. In January 2018, the FASB also issued additional guidance that provides for a practical expedient that allows entities to elect to not evaluate land easements as leases that exist or expired before the adoption date and were not previously accounted for as leases under current lease guidance. The Registrants plan to elect these practical expedients. The Registrants are currently assessing the impact of adopting this guidance and will adopt this standard as of the beginning of the period adopted, which will be January 1, 2019. Key implementation activities in process of being completed include identifying and implementing new controls and processes and compiling the required disclosure information. The Registrants expect an increase in assets and liabilities, which are still being quantified, but do not expect an impact to the Statements of Cash Flows or Statements of Income. Additional qualitative and quantitative disclosures around the nature of the Registrants’ leasing activity and information surrounding the amount, timing and uncertainty of cash flows arising from leases will also be provided upon adoption. 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 adoption of this guidance requires additional disclosures around the income statement impacts of hedging activities as well as removing disclosures related to ineffectiveness. Other impacts of adopting this guidance are not expected to be material. The Registrants will adopt 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. (PPL, LKE, LG&E and KU) Simplifying the Test for Goodwill Impairment 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. (PPL and LKE) Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income In February 2018, the FASB issued accounting guidance that gives entities the option to reclassify tax effects stranded within AOCI as a result of the TCJA to retained earnings. The reclassification applies only to those stranded tax effects arising from the TCJA enactment. Certain disclosures related to the stranded tax effects, including a description of the accounting policy for releasing income tax effects from AOCI, are required. For all entities, this guidance is effective for fiscal years beginning after December 15, 2018 and interim periods within those fiscal years. Early adoption is permitted, including adoption in any interim period. The amendments should be applied either in the period of adoption or retrospectively to each period in which the effect of the change in the U.S. federal corporate income tax rate in the TCJA is recognized. The adoption of this guidance will result in PPL and LKE reclassifying $50 million and $18 million of deferred tax effects (primarily related to pension and other post-retirement benefits) stranded in AOCI as a result of the TCJA to retained earnings. The Registrants are assessing the period in which they will adopt this guidance.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncements, Policy	(All Registrants) The following accounting policy disclosures represent updates to Note 1 in each Registrant's 2017 Form 10-K and should be read in conjunction with those disclosures. Income Taxes 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 is 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. 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 the three and nine months ended September 30, 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 September 30, 2018 with respect to the three items discussed above. The Registrants continue to analyze the impact of the TCJA on the deductibility of executive compensation awarded on or before November 2, 2017. The Registrants do not currently anticipate a material change from what was reflected in the December 31, 2017 financial statements and expect to record the impact, if any, of changes in the deductibility of executive compensation in the fourth quarter of 2018. New Accounting Guidance Adopted Accounting for Revenue from Contracts with Customers Effective January 1, 2018, the Registrants adopted accounting guidance that establishes a comprehensive new model for the recognition of revenue from contracts with customers. This model is based on the core principle that revenue should be recognized to depict the transfer of control of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Registrants adopted this guidance using the modified retrospective transition method. No cumulative effect adjustment was required as of the January 1, 2018 adoption date. The adoption of this guidance did not have a material impact on the Registrants' revenue recognition policies. See Note 4 for the required disclosures resulting from the adoption of this standard. Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost Effective January 1, 2018, the Registrants adopted accounting guidance that changes the income statement presentation of net periodic benefit cost. Retrospectively, this guidance requires the service cost component to be disaggregated from other components of net benefit cost and presented in the same income statement line items as other employee compensation costs arising from services rendered during the period. The other components of net periodic benefits are presented separately from the line items that include the service cost and outside of any subtotal of operating income. Prospectively, the guidance limits the capitalization to the service cost component of net periodic benefit costs. For PPL, the non-service cost components of net periodic benefit costs were in a net credit position for the three and nine months ended September 30, 2018 . The non-service cost credits that would have been capitalized under previous guidance, but are now recorded as income within "Other Income (Expense) - net," were $5 million ( $4 million after-tax or $0.01 per share) and $ 16 million ($ 13 million after-tax or $ 0.02 per share) for the three and nine months ended September 30, 2018 . For PPL Electric, LG&E and KU, non-service costs or credits that would have been capitalized under previous guidance are now recognized as a regulatory asset or regulatory liability, as applicable, in accordance with regulatory approvals. 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 on the Statements of Income as a result of the adoption. Three Months Nine Months 2018 2017 2018 2017 PPL $ 61 $ 41 $ 195 $ 123 PPL Electric 1 — 4 — LKE 1 (2 ) 3 (4 ) LG&E — (2 ) (1 ) (4 ) KU — — 2 (1 ) PPL and PPL Electric elected to use the practical expedient that permits using the amounts disclosed in the defined benefit plan note for the prior comparative period as the estimation basis for applying the retrospective presentation requirements. Presentation of Restricted Cash in the Statement of Cash Flows (PPL and PPL Electric) Effective January 1, 2018, PPL and PPL Electric adopted accounting guidance that changes the cash flow statement presentation of restricted cash. Under the new guidance, amounts considered restricted cash are presented with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total cash amounts on the Statements of Cash Flows. The guidance requires a reconciliation of the total cash, cash equivalents and restricted cash from the Statement of Cash Flows to amounts on the Balance Sheets and disclosure of the nature of the restrictions. PPL and PPL Electric have applied this guidance on a retrospective basis for all periods presented. The adoption of this guidance did not have a material impact on the Statements of Cash Flows. Reconciliation of Cash, Cash Equivalents and Restricted Cash The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL PPL Electric September 30, December 31, 2017 September 30, December 31, 2017 Cash and cash equivalents $ 842 $ 485 $ 414 $ 49 Restricted cash - current (a) 3 3 2 2 Restricted cash - noncurrent (a) 19 23 — — Total Cash, Cash Equivalents and Restricted Cash $ 864 $ 511 $ 416 $ 51 (a) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Transfer, Policy	Transfers between levels are recognized at end-of-reporting-period values.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Policies)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives, Offsetting Fair Value Amounts, Policy	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.

Adoption of Accounting Guidance

Adoption of Accounting Guidance (Tables)	9 Months Ended
	Sep. 30, 2018
Adoption of Accounting Guidance [Abstract]
Schedule of Non-Service Benefits Costs (Credits) [Table Text Block]	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 on the Statements of Income as a result of the adoption. Three Months Nine Months 2018 2017 2018 2017 PPL $ 61 $ 41 $ 195 $ 123 PPL Electric 1 — 4 — LKE 1 (2 ) 3 (4 ) LG&E — (2 ) (1 ) (4 ) KU — — 2 (1 )
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement	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 September 30, December 31, 2017 September 30, December 31, 2017 Cash and cash equivalents $ 842 $ 485 $ 414 $ 49 Restricted cash - current (a) 3 3 2 2 Restricted cash - noncurrent (a) 19 23 — — Total Cash, Cash Equivalents and Restricted Cash $ 864 $ 511 $ 416 $ 51 (a) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."

Segment and Related Informati_2

Segment and Related Information (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Segment and Related Information	Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended September 30 are as follows: Three Months Nine Months 2018 2017 2018 2017 Operating Revenues from external customers U.K. Regulated $ 517 $ 477 $ 1,716 $ 1,547 Kentucky Regulated 802 818 2,417 2,350 Pennsylvania Regulated 548 547 1,704 1,620 Corporate and Other 5 3 9 4 Total $ 1,872 $ 1,845 $ 5,846 $ 5,521 Net Income U.K. Regulated (a) $ 245 $ 126 $ 836 $ 560 Kentucky Regulated 122 125 332 299 Pennsylvania Regulated 112 95 335 251 Corporate and Other (34 ) 9 (91 ) (60 ) Total $ 445 $ 355 $ 1,412 $ 1,050 (a) Includes unrealized gains and losses from hedging foreign currency economic activity. See Note 14 for additional information. The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: September 30, December 31, Assets U.K. Regulated (a) $ 16,823 $ 16,813 Kentucky Regulated 14,754 14,468 Pennsylvania Regulated 11,110 10,082 Corporate and Other (b) 355 116 Total $ 43,042 $ 41,479 (a) Includes $12.4 billion and $12.5 billion of net PP&E as of September 30, 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 and the elimination of inter-segment transactions.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2018
Revenue from Contracts with Customers [Line Items]
Reconciliation of Revenue from Contracts with Customers [Table Text Block]	The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended September 30, 2018 . Three Months PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 1,872 $ 548 $ 802 $ 362 $ 447 Revenues derived from: Alternative revenue programs (b) (4 ) (3 ) (1 ) (4 ) 3 Other (c) (15 ) (3 ) (5 ) (2 ) (3 ) Revenues from Contracts with Customers $ 1,853 $ 542 $ 796 $ 356 $ 447 Nine Months PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 5,846 $ 1,704 $ 2,417 $ 1,116 $ 1,332 Revenues derived from: Alternative revenue programs (b) 37 (1 ) 38 16 22 Other (c) (43 ) (9 ) (14 ) (5 ) (9 ) Revenues from Contracts with Customers $ 5,840 $ 1,694 $ 2,441 $ 1,127 $ 1,345 (a) PPL includes $517 million and $1.7 billion for the three and nine months ended September 30, 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 3 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 tables show revenues from contracts with customers disaggregated by customer class for the periods ended September 30, 2018 . Three Months PPL PPL Electric LKE LG&E KU Licensed energy suppliers (a) $ 475 $ — $ — $ — $ — Residential 647 328 319 162 157 Commercial 307 88 219 112 107 Industrial 156 12 144 45 99 Other (b) 119 14 65 27 39 Wholesale - municipal 30 — 30 — 30 Wholesale - other (c) 19 — 19 10 15 Transmission 100 100 — — — Revenues from Contracts with Customers $ 1,853 $ 542 $ 796 $ 356 $ 447 Nine Months PPL PPL Electric LKE LG&E KU Licensed energy suppliers (a) $ 1,606 $ — $ — $ — $ — Residential 2,039 1,036 1,003 505 498 Commercial 928 275 653 343 310 Industrial 466 37 429 134 295 Other (b) 339 40 200 88 113 Wholesale - municipal 91 — 91 — 91 Wholesale - other (c) 65 — 65 57 38 Transmission 306 306 — — — Revenues from Contracts with Customers $ 5,840 $ 1,694 $ 2,441 $ 1,127 $ 1,345 (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 Contracts with Customers [Table Text Block]	The following table shows the accounts receivable balances that were impaired for the periods ended September 30, 2018 . Three Months Nine Months PPL $ 11 $ 24 PPL Electric 7 17 LKE 4 7 LG&E 2 3 KU 2 4
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 September 30, 2018 40 17 8 4 4
Contract With Customer Liability Revenue Recognized [Table Text Block]	The following table shows the revenue recognized during the period ended September 30, 2018 that was included in the contract liability balance at December 31, 2017. Nine Months PPL $ 22 PPL Electric 8 LKE 8 LG&E 4 KU 4

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 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 September 30 used in the EPS calculation are: Three Months Nine Months 2018 2017 2018 2017 Income (Numerator) Net income $ 445 $ 355 $ 1,412 $ 1,050 Less amounts allocated to participating securities 1 1 2 2 Net income available to PPL common shareowners - Basic and Diluted $ 444 $ 354 $ 1,410 $ 1,048 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 703,730 686,563 699,117 683,783 Add incremental non-participating securities: Share-based payment awards 298 2,183 427 2,298 Forward sale agreements 6,489 — 2,761 — Weighted-average shares - Diluted EPS 710,517 688,746 702,305 686,081 Basic EPS Net Income available to PPL common shareowners $ 0.63 $ 0.52 $ 2.02 $ 1.53 Diluted EPS Net Income available to PPL common shareowners $ 0.62 $ 0.51 $ 2.01 $ 1.53
Common Stock Issuances	For the periods ended September 30 , PPL issued common stock related to stock-based compensation plans and the DRIP as follows (in thousands): Three Months Nine Months 2018 2017 2018 2017 Stock-based compensation plans (a) 80 256 568 1,707 DRIP 493 355 1,504 1,169 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock units and conversion of stock units granted to directors.
Antidilutive Securities Excluded From Diluted EPS	For the periods ended September 30 , the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months Nine Months 2018 2017 2018 2017 Stock options 15 696 229 696 Restricted stock units 2 — 15 —

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2018
Income Taxes [Line Items]
Tax Reform	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 the three and nine months ended September 30, 2018 are as follows. Taxable Income (Loss) (a) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision September 30, 2018 Adjustment 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, 2023. 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 September 30, 2018 Adjustment 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 (a) 229 220 9 Total $ 321 $ 321 $ — Income Tax Expense (Benefit) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision September 30, 2018 Adjustment PPL Electric Reduction in U.S. federal income tax rate (a) $ (13 ) $ (13 ) $ — LKE Reduction in U.S. federal income tax rate (a) $ 110 $ 112 $ (2 ) (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended September 30 are as follows. (PPL) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 115 $ 165 $ 373 $ 480 Increase (decrease) due to: State income taxes, net of federal income tax benefit 9 14 34 37 Valuation allowance adjustments 5 4 17 9 Impact of lower U.K. income tax rates relative to U.S. income tax rates (a) (7 ) (45 ) (20 ) (133 ) U.S. income tax on foreign earnings - net of foreign tax credit (a) (b) 1 (8 ) 2 (24 ) Federal and state tax reserve adjustments — — 3 — Impact of the U.K. Finance Acts (4 ) (3 ) (7 ) (12 ) Depreciation and other items not normalized (1 ) (2 ) (4 ) (7 ) Amortization of excess deferred income taxes (a) (11 ) — (30 ) — Deferred tax impact of state tax reform (c) — — 9 — Interest benefit on U.K. financing entities (4 ) (4 ) (13 ) (12 ) Stock-based compensation — — 1 (7 ) Other — (5 ) (3 ) (10 ) Total increase (decrease) (12 ) (49 ) (11 ) (159 ) Total income taxes $ 103 $ 116 $ 362 $ 321 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) Lower income taxes in 2017 primarily due to the tax benefit of accelerated pension contributions made in the first quarter of 2017. The related tax benefit was recognized over the annual period as a result of utilizing an estimated annual effective tax rate. (c) During the second quarter of 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.
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended September 30 are as follows. (PPL Electric) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 30 $ 56 $ 93 $ 144 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 9 35 26 Depreciation and other items not normalized (1 ) (1 ) (4 ) (5 ) Amortization of excess deferred income taxes (a) (5 ) — (13 ) — Stock-based compensation — — — (5 ) Other (1 ) — — (1 ) Total increase (decrease) 5 8 18 15 Total income taxes $ 35 $ 64 $ 111 $ 159 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.
LG And E And KU Energy LLC [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended September 30 are as follows. (LKE) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 34 $ 74 $ 97 $ 181 Increase (decrease) due to: State income taxes, net of federal income tax benefit (b) 6 8 17 19 Amortization of investment tax credit (1 ) (1 ) (3 ) (2 ) Deferred tax impact of U.S. tax reform (a) (2 ) — (2 ) — Deferred tax impact of state tax reform (c) — — 9 — Amortization of excess deferred income taxes (a) (3 ) — (14 ) — Other (2 ) (2 ) (2 ) (3 ) Total increase (decrease) (2 ) 5 5 14 Total income taxes $ 32 $ 79 $ 102 $ 195 (a) (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018. (c) During the second quarter of 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.
Louisville Gas And Electric Co [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended September 30 are as follows. (LG&E) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 18 $ 36 $ 50 $ 91 Increase (decrease) due to: State income taxes, net of federal income tax benefit (b) 3 4 9 10 Amortization of excess deferred income taxes (a) (1 ) — (6 ) — Other (2 ) (1 ) (2 ) (2 ) Total increase (decrease) — 3 1 8 Total income taxes $ 18 $ 39 $ 51 $ 99 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018.
Kentucky Utilities Co [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended September 30 are as follows. (KU) Three Months Nine Months 2018 2017 2018 2017 Federal income tax on Income Before Income Taxes at statutory tax rate (a) $ 21 $ 43 $ 60 $ 111 Increase (decrease) due to: State income taxes, net of federal income tax benefit (b) 3 5 10 11 Amortization of excess deferred income taxes (a) (2 ) — (8 ) — Other (1 ) (1 ) (3 ) (2 ) Total increase (decrease) — 4 (1 ) 9 Total income taxes $ 21 $ 47 $ 59 $ 120 (a) The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. (b) The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	9 Months Ended
	Sep. 30, 2018
Utility Rate Regulation [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric September 30, December 31, September 30, December 31, Current Regulatory Assets: Environmental cost recovery $ — $ 5 $ — $ — Generation formula rate — 6 — — Smart meter rider 16 15 16 15 Plant outage costs 7 3 — — Gas supply clause 3 4 — — Other 3 1 2 1 Total current regulatory assets (a) $ 29 $ 34 $ 18 $ 16 PPL PPL Electric September 30, December 31, September 30, December 31, Noncurrent Regulatory Assets: Defined benefit plans $ 847 $ 880 $ 486 $ 504 Taxes recoverable through future rates 3 3 3 3 Storm costs (b) 45 33 22 — Unamortized loss on debt 47 54 23 29 Interest rate swaps 18 26 — — Terminated interest rate swaps 88 92 — — Accumulated cost of removal of utility plant 190 173 190 173 AROs 267 234 — — Act 129 compliance rider 12 — 12 — Other 8 9 2 — Total noncurrent regulatory assets $ 1,525 $ 1,504 $ 738 $ 709 PPL PPL Electric September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 35 $ 34 $ 35 $ 34 Transmission service charge 2 9 2 9 Environmental cost recovery 22 1 — — Universal service rider 23 26 23 26 Transmission formula rate 8 9 8 9 Fuel adjustment clause 7 3 — — TCJA customer refund (c) 26 — — — Storm damage expense rider 4 8 4 8 Other 9 5 — — Total current regulatory liabilities $ 136 $ 95 $ 72 $ 86 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 678 $ 677 $ — $ — Power purchase agreement - OVEC (d) 62 68 — — Net deferred taxes (e) 1,846 1,853 642 668 Defined benefit plans 33 27 — — Terminated interest rate swaps 72 74 — — TCJA customer refund (f) 41 — 41 — Other 7 5 3 — Total noncurrent regulatory liabilities $ 2,739 $ 2,704 $ 686 $ 668 LKE LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Assets: Plant outage costs $ 7 $ 3 $ 7 $ 3 $ — $ — Generation formula rate — 6 — — — 6 Gas supply clause 3 4 3 4 — — Other 1 5 1 5 — — Total current regulatory assets $ 11 $ 18 $ 11 $ 12 $ — $ 6 LKE LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, Noncurrent Regulatory Assets: Defined benefit plans $ 361 $ 376 $ 227 $ 234 $ 134 $ 142 Storm costs 23 33 12 18 11 15 Unamortized loss on debt 24 25 15 16 9 9 Interest rate swaps 18 26 18 26 — — Terminated interest rate swaps 88 92 52 54 36 38 AROs 267 234 74 61 193 173 Other 6 9 2 2 4 7 Total noncurrent regulatory assets $ 787 $ 795 $ 400 $ 411 $ 387 $ 384 LKE LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Environmental cost recovery $ 22 $ 1 $ 11 $ — $ 11 $ 1 Fuel adjustment clause 7 3 — — 7 3 Gas line tracker 2 3 2 3 — — TCJA customer refund (c) 26 — 12 — 14 — Other 7 2 1 — 6 2 Total current regulatory liabilities $ 64 $ 9 $ 26 $ 3 $ 38 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 678 $ 677 $ 280 $ 282 $ 398 395 Power purchase agreement - OVEC (d) 62 68 43 47 19 21 Net deferred taxes (e) 1,204 1,185 560 552 644 633 Defined benefit plans 33 27 — — 33 27 Terminated interest rate swaps 72 74 36 37 36 37 Other 4 5 1 1 3 4 Total noncurrent regulatory liabilities $ 2,053 $ 2,036 $ 920 $ 919 $ 1,133 $ 1,117 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b) Storm costs incurred in PPL Electric's territory from a March 2018 storm will be amortized from 2019 through 2021. (c) Relates to estimated amounts owed to LG&E and KU customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, effective January 1, 2018. Amounts owed will be distributed through the TCJA bill credit. (d) This liability was recorded as an offset to an intangible asset that was recorded at fair value upon the acquisition of LKE by PPL. (e) Primarily relates to excess deferred taxes recorded as a result of the TCJA, which reduced the U.S. federal corporate income tax rate effective January 1, 2018, requiring deferred tax balances and the associated regulatory liabilities to be remeasured as of December 31, 2017. LG&E and KU began distributing amounts through the TCJA bill credit effective April 1, 2018. (f) Relates to amounts owed to PPL Electric customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, for the period of January 1, 2018 through June 30, 2018 which is not yet reflected in distribution customer rates. The distribution method back to customers of this liability must be proposed to the PUC at the earlier of May 2021 or PPL Electric’s next rate case.

Financing Activities (Tables)

Financing Activities (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The following credit facilities were in place at: September 30, 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) Jan. 2023 £ 210 £ 154 £ — £ 54 £ 148 £ — Term Loan Facility (b) Dec. 2018 130 130 — — — — WPD (South West) Syndicated Credit Facility July 2021 245 — — 245 — — WPD (East Midlands) Syndicated Credit Facility (c) July 2021 300 93 — 207 180 — WPD (West Midlands) Syndicated Credit Facility (d) July 2021 300 50 — 250 120 — Uncommitted Credit Facilities 130 — 4 126 — 4 Total U.K. Credit Facilities (e) £ 1,315 £ 427 £ 4 £ 882 £ 448 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility Jan. 2023 $ 950 $ — $ 691 $ 259 $ — $ 230 Syndicated Credit Facility Nov. 2018 300 — — 300 — — Bilateral Credit Facility Mar. 2019 100 — 20 80 — 18 Total PPL Capital Funding Credit Facilities $ 1,350 $ — $ 711 $ 639 $ — $ 248 PPL Electric Syndicated Credit Facility Jan. 2023 $ 650 $ — $ 1 $ 649 $ — $ 1 LKE Syndicated Credit Facility Oct. 2018 $ 75 $ — $ — $ 75 $ — $ — LG&E Syndicated Credit Facility Jan. 2023 $ 500 $ — $ 176 $ 324 $ — $ 199 Term Loan Credit Facility Oct. 2019 200 200 — — 100 — Total LG&E Credit Facilities $ 700 $ 200 $ 176 $ 324 $ 100 $ 199 September 30, 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 KU Syndicated Credit Facility Jan. 2023 $ 400 $ — $ 128 $ 272 $ — $ 45 Letter of Credit Facility Oct. 2020 198 — 198 — — 198 Total KU Credit Facilities $ 598 $ — $ 326 $ 272 $ — $ 243 (a) The amounts borrowed at September 30, 2018 and December 31, 2017 were USD-denominated borrowings of $200 million for both periods, which bore interest at 2.90% and 2.17% . The unused capacity reflects the amount borrowed in GBP of £156 million as of the date borrowed. (b) The amount borrowed at September 30, 2018 was a GBP-denominated borrowing which equated to $168 million and bore interest at 1.97% . (c) The amounts borrowed at September 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $121 million and $244 million and bore interest at 1.09% and 0.89% . (d) The amounts borrowed at September 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $65 million and $162 million and bore interest at 1.12% and 0.89% . (e) At September 30, 2018 , the unused capacity under the U.K. credit facilities was $1.1 billion .
Schedule of Short-term Debt	The following commercial paper programs were in place at: September 30, 2018 December 31, 2017 Weighted - Average Interest Rate Capacity Commercial Paper Issuances Unused Capacity Weighted - Average Interest Rate Commercial Paper Issuances PPL Capital Funding 2.38% $ 1,000 $ 691 $ 309 1.64% $ 230 PPL Electric 650 — 650 — LG&E 2.34% 350 176 174 1.83% 199 KU 2.34% 350 128 222 1.97% 45 Total $ 2,350 $ 995 $ 1,355 $ 474

Defined Benefits (Tables)

Defined Benefits (Tables)	9 Months Ended
	Sep. 30, 2018
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE, and LG&E for the periods ended September 30 : Pension Benefits Three Months Nine Months U.S. U.K. U.S. U.K. 2018 2017 2018 2017 2018 2017 2018 2017 PPL Service cost $ 15 $ 17 $ 21 $ 20 $ 46 $ 49 $ 63 $ 57 Interest cost 39 42 46 45 117 126 140 132 Expected return on plan assets (62 ) (58 ) (145 ) (130 ) (186 ) (173 ) (445 ) (382 ) Amortization of: Prior service cost 2 2 — — 7 7 — — Actuarial loss 22 18 37 36 63 52 114 107 Net periodic defined benefit costs (credits) before settlements and special termination benefits 16 21 (41 ) (29 ) 47 61 (128 ) (86 ) Settlements (a) — 1 — — — 1 — — Special termination benefits (b) — — — — — 1 — — Net periodic defined benefit costs (credits) $ 16 $ 22 $ (41 ) $ (29 ) $ 47 $ 63 $ (128 ) $ (86 ) (a) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 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. (b) Enhanced pension benefits offered to certain PPL Electric bargaining unit employees under a one-time voluntary retirement window offered as part of the new five year IBEW contract ratified in March 2017. Other Postretirement Benefits Three Months Nine Months 2018 2017 2018 2017 PPL Service cost $ 1 $ 2 $ 5 $ 6 Interest cost 5 5 15 17 Expected return on plan assets (4 ) (6 ) (17 ) (17 ) Amortization of prior service cost — — — (1 ) Amortization of actuarial loss — 1 — 1 Net periodic defined benefit costs $ 2 $ 2 $ 3 $ 6
PPL Electric Utilities Corp [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Allocation of Net Periodic Benefit Costs	For the periods ended September 30 , PPL Services allocated the following net periodic defined benefit costs to PPL Electric, and LKE allocated the following net periodic defined benefit costs to LG&E and KU: Three Months Nine Months 2018 2017 2018 2017 PPL Electric $ 5 $ 6 $ 12 $ 19 LG&E 1 3 5 8 KU 1 2 3 7
LG And E And KU Energy LLC [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE, and LG&E for the periods ended September 30 : Pension Benefits Three Months Nine Months 2018 2017 2018 2017 LKE Service cost $ 6 $ 6 $ 18 $ 18 Interest cost 16 17 48 51 Expected return on plan assets (25 ) (23 ) (76 ) (69 ) Amortization of: Prior service cost 3 2 7 6 Actuarial loss (a) 8 8 26 23 Net periodic defined benefit costs (b) $ 8 $ 10 $ 23 $ 29 (a) As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LKE's accounting policy and actuarial loss calculated using a 15 -year amortization period was $2 million and $8 million for the three and nine months ended September 30, 2018 and $3 million and $8 million for the three and nine months ended September 30, 2017. This difference is recorded as a regulatory asset. (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 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. Other Postretirement Benefits Three Months Nine Months 2018 2017 2018 2017 LKE Service cost $ 1 $ 1 $ 3 $ 3 Interest cost 2 2 6 6 Expected return on plan assets (2 ) (2 ) (6 ) (5 ) Amortization of: Prior service cost — 1 1 1 Actuarial gain — — (1 ) — Net periodic defined benefit costs $ 1 $ 2 $ 3 $ 5
Louisville Gas And Electric Co [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE, and LG&E for the periods ended September 30 : Pension Benefits Three Months Nine Months 2018 2017 2018 2017 LG&E Service cost $ — $ — $ 1 $ 1 Interest cost 3 3 9 9 Expected return on plan assets (6 ) (5 ) (17 ) (16 ) Amortization of: Prior service cost 1 1 4 3 Actuarial loss (a) 2 3 5 7 Net periodic defined benefit costs (b) $ — $ 2 $ 2 $ 4 (a) As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LG&E's accounting policy and actuarial loss calculated using a 15 -year amortization period was $1 million for the nine months ended September 30, 2018 and $1 million and $3 million for the three and nine months ended September 30, 2017. This difference is recorded as a regulatory asset. (b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 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.
Allocation of Net Periodic Benefit Costs	For the periods ended September 30 , PPL Services allocated the following net periodic defined benefit costs to PPL Electric, and LKE allocated the following net periodic defined benefit costs to LG&E and KU: Three Months Nine Months 2018 2017 2018 2017 PPL Electric $ 5 $ 6 $ 12 $ 19 LG&E 1 3 5 8 KU 1 2 3 7
Kentucky Utilities Co [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Allocation of Net Periodic Benefit Costs	For the periods ended September 30 , PPL Services allocated the following net periodic defined benefit costs to PPL Electric, and LKE allocated the following net periodic defined benefit costs to LG&E and KU: Three Months Nine Months 2018 2017 2018 2017 PPL Electric $ 5 $ 6 $ 12 $ 19 LG&E 1 3 5 8 KU 1 2 3 7

Commitments and Contingencies (

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Guarantees	The table below details guarantees provided as of September 30, 2018 . Exposure at Expiration 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 81 (c) PPL Electric Guarantee of inventory value 15 (d) 2020 LKE Indemnification of lease termination and other divestitures 200 (e) 2021 LG&E and KU LG&E and KU guarantee 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 September 30, 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. (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. (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 $114 million at September 30, 2018 , consisting of LG&E's share of $79 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" in Note 13 in PPL's, LKE's, LG&E's and KU's 2017 Form 10-K 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 is seeking to reject the OVEC power purchase contract, which action OVEC and certain sponsors are contesting. 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.

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134
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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134
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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134
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 periods ended September 30 , 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. Three Months Nine Months 2018 2017 2018 2017 PPL Electric from PPL Services $ 14 $ 43 $ 45 $ 138 LKE from PPL Services 5 4 19 15 PPL Electric from PPL EU Services 34 15 110 48 LG&E from LKS 36 38 113 120 KU from LKS 42 43 127 134

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	9 Months Ended
	Sep. 30, 2018
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended September 30 , were: Three Months Nine Months 2018 2017 2018 2017 Other Income Economic foreign currency exchange contracts (Note 14) $ 40 $ (81 ) $ 92 $ (237 ) Defined benefit plans - non-service credits (Note 9) 61 41 195 123 Interest income 3 1 5 2 AFUDC - equity component 5 5 15 11 Miscellaneous 2 2 3 11 Total Other Income 111 (32 ) 310 (90 ) Other Expense Charitable contributions 1 1 6 6 Miscellaneous 4 2 7 16 Total Other Expense 5 3 13 22 Other Income (Expense) - net $ 106 $ (35 ) $ 297 $ (112 )
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended September 30 , were: Three Months Nine Months 2018 2017 2018 2017 Other Income AFUDC - equity component $ 5 $ 5 $ 15 $ 11 Defined benefit plans - non-service credits (Note 9) 1 — 4 — Miscellaneous — — 1 — Total Other Income 6 5 20 11 Other Expense Charitable contributions 1 1 2 2 Miscellaneous — — — 1 Total Other Expense 1 1 2 3 Other Income (Expense) - net $ 5 $ 4 $ 18 $ 8

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were: September 30, 2018 December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 842 $ 842 $ — $ — $ 485 $ 485 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 26 26 — — Special use funds (a) 63 63 — — — — — — Price risk management assets (b): Foreign currency contracts 174 — 174 — 163 — 163 — Cross-currency swaps 123 — 123 — 101 — 101 — Total price risk management assets 297 — 297 — 264 — 264 — Total assets $ 1,224 $ 927 $ 297 $ — $ 775 $ 511 $ 264 $ — September 30, 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 $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — Foreign currency contracts 30 — 30 — 148 — 148 — Total price risk management liabilities $ 49 $ — $ 49 $ — $ 174 $ — $ 174 $ — PPL Electric Assets Cash and cash equivalents $ 414 $ 414 $ — $ — $ 49 $ 49 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 416 $ 416 $ — $ — $ 51 $ 51 $ — $ — LKE Assets Cash and cash equivalents $ 29 $ 29 $ — $ — $ 30 $ 30 $ — $ — Total assets $ 29 $ 29 $ — $ — $ 30 $ 30 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — LG&E Assets Cash and cash equivalents $ 11 $ 11 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 11 $ 11 $ — $ — $ 15 $ 15 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — Total price risk management liabilities $ 19 $ — $ 19 $ — $ 26 $ — $ 26 $ — KU Assets Cash and cash equivalents $ 18 $ 18 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 18 $ 18 $ — $ — $ 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, by Balance Sheet Grouping	The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. September 30, 2018 December 31, 2017 Carrying Fair Value Carrying Fair Value PPL $ 20,254 $ 23,023 $ 20,195 $ 23,783 PPL Electric 3,693 3,899 3,298 3,769 LKE 5,501 5,783 5,159 5,670 LG&E 1,808 1,879 1,709 1,865 KU 2,320 2,467 2,328 2,605 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments And Hedging Activities [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets. September 30, 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) 5 — — — 4 — — — Foreign currency contracts — — 86 22 — — 45 67 Total current 5 — 86 26 4 — 45 71 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 15 — — — 22 Cross-currency swaps (b) 118 — — — 97 — — — Foreign currency contracts — — 88 8 — — 118 81 Total noncurrent 118 — 88 23 97 — 118 103 Total derivatives $ 123 $ — $ 174 $ 49 $ 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.
Derivative Instruments, Gain (Loss)	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the periods ended September 30, 2018 . Three Months Nine Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Nine Months Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ (2 ) $ — $ (6 ) $ — Cross-currency swaps 27 26 Interest expense 1 — 1 — Other income (expense) - net 18 — 30 — Total $ 27 $ 26 $ 17 $ — $ 25 $ — Net Investment Hedges: Foreign currency contracts $ — $ 11 Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Nine Months Foreign currency contracts Other income (expense) - net $ 40 $ 92 Interest rate swaps Interest expense (1 ) (4 ) Total $ 39 $ 88 Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 2 $ 7 The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the periods ended September 30, 2017 . Three Months Nine Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Nine Months Cash Flow Hedges: Interest rate swaps $ — $ (2 ) Interest expense $ (2 ) $ — $ (6 ) $ (1 ) Cross-currency swaps 1 (34 ) Interest expense 1 — 1 — Other income (expense) - net 2 — (24 ) — Total $ 1 $ (36 ) $ 1 $ — $ (29 ) $ (1 ) Net Investment Hedges: Foreign currency contracts $ 1 $ 1 Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Nine Months Foreign currency contracts Other income (expense) - net $ (81 ) $ (237 ) Interest rate swaps Interest expense (1 ) (4 ) Total $ (82 ) $ (241 ) Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 1 $ 2
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 September 30, 2018 Treasury Derivatives PPL $ 297 $ 28 $ 25 $ 244 $ 49 $ 28 $ — $ 21 LKE — — — — 19 — — 19 LG&E — — — — 19 — — 19 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 September 30, 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 $ 8 $ 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) 8 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]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. September 30, 2018 December 31, 2017 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 4 $ — $ 4 Total current — 4 — 4 September 30, 2018 December 31, 2017 Assets Liabilities Assets Liabilities Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 15 — 22 Total noncurrent — 15 — 22 Total derivatives $ — $ 19 $ — $ 26
Derivative Instruments, Gain (Loss)	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, 2018 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ (1 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 2 $ 7 The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, 2017 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ (1 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 1 $ 2
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 September 30, 2018 Treasury Derivatives PPL $ 297 $ 28 $ 25 $ 244 $ 49 $ 28 $ — $ 21 LKE — — — — 19 — — 19 LG&E — — — — 19 — — 19 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 September 30, 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 $ 8 $ 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) 8 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]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. September 30, 2018 December 31, 2017 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 4 $ — $ 4 Total current — 4 — 4 September 30, 2018 December 31, 2017 Assets Liabilities Assets Liabilities Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 15 — 22 Total noncurrent — 15 — 22 Total derivatives $ — $ 19 $ — $ 26
Derivative Instruments, Gain (Loss)	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, 2018 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ (1 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 2 $ 7 The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, 2017 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ (1 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 1 $ 2
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 September 30, 2018 Treasury Derivatives PPL $ 297 $ 28 $ 25 $ 244 $ 49 $ 28 $ — $ 21 LKE — — — — 19 — — 19 LG&E — — — — 19 — — 19 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 September 30, 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 $ 8 $ 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) 8 6 6 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 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 Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210
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 Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210
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 Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210
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 Balance at December 31, 2017 $ 397 $ 356 $ 121 $ 235 Accretion 14 13 5 8 Obligations incurred 8 8 — 8 Effect of foreign exchange rates (2 ) — — — Changes in estimated timing or cost (6 ) (14 ) (2 ) (12 ) Obligations settled (46 ) (46 ) (17 ) (29 ) Balance at September 30, 2018 $ 365 $ 317 $ 107 $ 210

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Sep. 30, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the periods ended September 30 were as follows. Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL June 30, 2018 $ (1,223 ) $ (21 ) $ — $ (7 ) $ (2,244 ) $ (3,495 ) Amounts arising during the period (187 ) 22 — — (8 ) (173 ) Reclassifications from AOCI — (14 ) — — 34 20 Net OCI during the period (187 ) 8 — — 26 (153 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Amounts arising during the period (321 ) 21 — (1 ) (9 ) (310 ) Reclassifications from AOCI — (21 ) — 1 104 84 Net OCI during the period (321 ) — — — 95 (226 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) Amounts arising during the period (12 ) 1 — — (3 ) (14 ) Reclassifications from AOCI — — — — 34 34 Net OCI during the period (12 ) 1 — — 31 20 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 195 (29 ) — — (14 ) 152 Reclassifications from AOCI — 24 1 1 97 123 Net OCI during the period 195 (5 ) 1 1 83 275 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) LKE June 30, 2018 $ — $ (8 ) $ (78 ) $ (86 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 1 2 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) December 31, 2017 $ — $ (9 ) $ (79 ) $ (88 ) Reclassifications from AOCI — 2 2 4 Net OCI during the period — 2 2 4 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) Amounts arising during the period — — (1 ) (1 ) Reclassifications from AOCI — — 1 1 Net OCI during the period — — — — September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (12 ) (12 ) Reclassifications from AOCI 1 1 3 5 Net OCI during the period 1 1 (9 ) (7 ) September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 )
Reclassification out of Other Comprehensive Income (Loss)	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the periods ended September 30 . Three Months Nine Months Affected Line Item on the Details about AOCI 2018 2017 2018 2017 Statements of Income Qualifying derivatives Interest rate swaps $ (2 ) $ (2 ) $ (6 ) $ (7 ) Interest Expense Cross-currency swaps 18 2 30 (24 ) Other Income (Expense) - net 1 1 1 1 Interest Expense Total Pre-tax 17 1 25 (30 ) Income Taxes (3 ) (1 ) (4 ) 6 Total After-tax 14 — 21 (24 ) Equity investees' AOCI — — — (1 ) Other Income (Expense) - net Total Pre-tax — — — (1 ) Income Taxes — — — — Total After-tax — — — (1 ) Defined benefit plans Prior service costs (a) (1 ) (1 ) (2 ) (2 ) Net actuarial loss (a) (42 ) (44 ) (130 ) (125 ) Total Pre-tax (43 ) (45 ) (132 ) (127 ) Income Taxes 9 11 27 29 Total After-tax (34 ) (34 ) (105 ) (98 ) Total reclassifications during the period $ (20 ) $ (34 ) $ (84 ) $ (123 ) (a) These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the periods ended September 30 were as follows. Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total PPL June 30, 2018 $ (1,223 ) $ (21 ) $ — $ (7 ) $ (2,244 ) $ (3,495 ) Amounts arising during the period (187 ) 22 — — (8 ) (173 ) Reclassifications from AOCI — (14 ) — — 34 20 Net OCI during the period (187 ) 8 — — 26 (153 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) December 31, 2017 $ (1,089 ) $ (13 ) $ — $ (7 ) $ (2,313 ) $ (3,422 ) Amounts arising during the period (321 ) 21 — (1 ) (9 ) (310 ) Reclassifications from AOCI — (21 ) — 1 104 84 Net OCI during the period (321 ) — — — 95 (226 ) September 30, 2018 $ (1,410 ) $ (13 ) $ — $ (7 ) $ (2,218 ) $ (3,648 ) June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) Amounts arising during the period (12 ) 1 — — (3 ) (14 ) Reclassifications from AOCI — — — — 34 34 Net OCI during the period (12 ) 1 — — 31 20 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) Foreign currency translation adjustments Unrealized gains (losses) on qualifying derivatives Defined benefit plans Equity investees' AOCI Prior service costs Actuarial gain (loss) Total December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 195 (29 ) — — (14 ) 152 Reclassifications from AOCI — 24 1 1 97 123 Net OCI during the period 195 (5 ) 1 1 83 275 September 30, 2017 $ (1,432 ) $ (12 ) $ — $ (7 ) $ (2,052 ) $ (3,503 ) LKE June 30, 2018 $ — $ (8 ) $ (78 ) $ (86 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 1 2 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) December 31, 2017 $ — $ (9 ) $ (79 ) $ (88 ) Reclassifications from AOCI — 2 2 4 Net OCI during the period — 2 2 4 September 30, 2018 $ — $ (7 ) $ (77 ) $ (84 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) Amounts arising during the period — — (1 ) (1 ) Reclassifications from AOCI — — 1 1 Net OCI during the period — — — — September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (12 ) (12 ) Reclassifications from AOCI 1 1 3 5 Net OCI during the period 1 1 (9 ) (7 ) September 30, 2017 $ — $ (7 ) $ (70 ) $ (77 )

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	$ 61	$ 41	$ 195	$ 123
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	842		842		$ 485
Restricted Cash, Current	3		3		3
Restricted Cash, Noncurrent	19		19		23
Cash, Cash Equivalents and Restricted Cash	864	696	864	696	511	$ 365
Income Statement impact of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	5		16
Defined Benefit Plan Net Periodic Benefit (Cost) Credit Non Service, After tax	$ 4		$ 13
Defined Benefit Plan Net Periodic Benefit (Cost) Credit NonService, Per Share	$ 0.01		$ 0.02
Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	$ 61	41	$ 195	123
PPL Electric Utilities Corp [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	1	0	4	0
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	414		414		49
Restricted Cash, Current	2		2		2
Restricted Cash, Noncurrent	0		0		0
Cash, Cash Equivalents and Restricted Cash	416	245	416	245	51	15
PPL Electric Utilities Corp [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	1	0	4	0
LG And E And KU Energy LLC [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	29	40	29	40	30	13
LG And E And KU Energy LLC [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	1	(2)	3	(4)
Louisville Gas And Electric Co [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	11	9	11	9	15	5
Louisville Gas And Electric Co [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	0	(2)	(1)	(4)
Kentucky Utilities Co [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	18	31	18	31	$ 15	$ 7
Kentucky Utilities Co [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	$ 0	$ 0	$ 2	$ (1)

Segment and Related Informati_3

Segment and Related Information (Details) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)Integer	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 1,872	$ 1,845	$ 5,846	$ 5,521
Net Income		445	355	1,412	1,050
Balance Sheet Data [Abstract]
Assets		43,042		43,042		$ 41,479
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		548	547	1,704	1,620
Net Income	[1]	111	95	334	251
Balance Sheet Data [Abstract]
Assets		11,096		$ 11,096		10,082
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				2
LG And E And KU Energy LLC [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		802	818	$ 2,417	2,350
Net Income		130	132	358	322
Balance Sheet Data [Abstract]
Assets		15,088		$ 15,088		14,802
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
Louisville Gas And Electric Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		362	363	$ 1,116	1,078
Net Income	[1]	66	65	188	161
Balance Sheet Data [Abstract]
Assets		6,721		$ 6,721		6,559
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		447	460	$ 1,332	1,303
Net Income	[2]	77	77	225	196
Balance Sheet Data [Abstract]
Assets		8,400		$ 8,400		8,254
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
United Kingdom Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		517	477	$ 1,716	1,547
Net Income		245	126	836	560
Balance Sheet Data [Abstract]
Assets		16,823		16,823		16,813
Segment (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		12,400		12,400		12,500
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		802	818	2,417	2,350
Net Income		122	125	332	299
Balance Sheet Data [Abstract]
Assets		14,754		14,754		14,468
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		548	547	1,704	1,620
Net Income		112	95	335	251
Balance Sheet Data [Abstract]
Assets		11,110		11,110		10,082
Corporate and Other [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		5	3	9	4
Net Income		(34)	$ 9	(91)	$ (60)
Balance Sheet Data [Abstract]
Assets		$ 355		$ 355		$ 116
[1]	Net income equals comprehensive income.
[2]	Net income approximates comprehensive income.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)Days	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)
Revenue from Contracts with Customers [Line Items]
Operating Revenues	$ 1,872	$ 1,845	$ 5,846	$ 5,521
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	(4)		37
Other Revenue	(15)		(43)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,853		5,840
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	11		24
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	40		40		$ 29
Contract with Customer, Liability, Revenue Recognized			22
Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	475		1,606
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	647		2,039
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	307		928
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	156		466
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	119		339
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	30		91
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	19		65
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	100		306
Pennsylvania Regulated [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	548	547	$ 1,704	1,620
Number Of Days Due From Invoice Date | Days			21
United Kingdom Regulated [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	517	477	$ 1,716	1,547
Number Of Days Due From Invoice Date | Days			14
Kentucky Regulated [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	802	818	$ 2,417	2,350
Number Of Days Due From Invoice Date | Days			22
Corporate and Other [Member]
Revenue from Contracts with Customers [Line Items]
Revenue, Remaining Performance Obligation, Amount	65		$ 65
Operating Revenues	$ 5	3	9	4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability, Revenue Recognized			$ 44
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	12 months		12 months
PPL Electric [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			21
LGE [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
KU [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
PPL Electric Utilities Corp [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	$ 548	547	$ 1,704	1,620
Number Of Days Due From Invoice Date | Days			21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	(3)		$ 1
Other Revenue	(3)		9
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	542		1,694
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	7		17
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	17		17		19
Contract with Customer, Liability, Revenue Recognized			8
PPL Electric Utilities Corp [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	328		1,036
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	88		275
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	12		37
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	14		40
PPL Electric Utilities Corp [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
PPL Electric Utilities Corp [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
PPL Electric Utilities Corp [Member] | Distribution [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	442		1,400
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	100		306
LG And E And KU Energy LLC [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	802	818	2,417	2,350
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	(1)		38
Other Revenue	(5)		(14)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	796		2,441
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	4		7
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	8		8		8
Contract with Customer, Liability, Revenue Recognized			8
LG And E And KU Energy LLC [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
LG And E And KU Energy LLC [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	319		1,003
LG And E And KU Energy LLC [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	219		653
LG And E And KU Energy LLC [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	144		429
LG And E And KU Energy LLC [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	65		200
LG And E And KU Energy LLC [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	30		91
LG And E And KU Energy LLC [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	19		65
LG And E And KU Energy LLC [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		$ 0
LG And E And KU Energy LLC [Member] | LGE [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
LG And E And KU Energy LLC [Member] | KU [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
Louisville Gas And Electric Co [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	362	363	$ 1,116	1,078
Number Of Days Due From Invoice Date | Days			22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	(4)		$ 16
Other Revenue	(2)		(5)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	356		1,127
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	2		3
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	4		4		4
Contract with Customer, Liability, Revenue Recognized			4
Louisville Gas And Electric Co [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	162		505
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	112		343
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	45		134
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	27		88
Louisville Gas And Electric Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Louisville Gas And Electric Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	10		57
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Kentucky Utilities Co [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	447	$ 460	$ 1,332	$ 1,303
Number Of Days Due From Invoice Date | Days			22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	3		$ 22
Other Revenue	(3)		(9)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	447		1,345
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	2		4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	4		4		$ 4
Contract with Customer, Liability, Revenue Recognized			4
Kentucky Utilities Co [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	157		498
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	107		310
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	99		295
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	39		113
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	30		91
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	15		38
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 0		$ 0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income (Numerator) [Abstract]
Net Income	$ 445	$ 355	$ 1,412	$ 1,050
Less amounts allocated to participating securities	1	1	2	2
Net income available to PPL common shareowners - Basic	444	354	1,410	1,048
Net income available to PPL common shareowners - Diluted	$ 444	$ 354	$ 1,410	$ 1,048
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	703,730	686,563	699,117	683,783
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	298	2,183	427	2,298
Forward sale agreements	6,489	0	2,761	0
Weighted-average shares - Diluted EPS (in shares)	710,517	688,746	702,305	686,081
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.63	$ 0.52	$ 2.02	$ 1.53
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.62	$ 0.51	$ 2.01	$ 1.53
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	80	256	568	1,707
Common stock issued under dividend reinvestment plan (in shares)	493	355	1,504	1,169
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	15	696	229	696
Restricted Stock Units (RSUs) [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	2	0	15	0

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 115		$ 165	$ 373	$ 480
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	9		14	34	37
Valuation allowance adjustments	5		4	17	9
Impact of lower U.K. income tax rates relative to U.S. income tax rates	(7)		(45)	(20)	(133)
U.S. income tax on foreign earnings - net of foreign tax credit	1		(8)	2	(24)
Federal and state tax reserve adjustments	0		0	3	0
Impact of the U.K. Finance Acts	(4)		(3)	(7)	(12)
Depreciation and other items not normalized	(1)		(2)	(4)	(7)
Amortization of excess deferred income taxes	(11)		0	(30)	0
Deferred tax impact of state tax reform	0		0	9	0
Interest benefit on U.K. financing entities	(4)		(4)	(13)	(12)
Stock-based compensation	0		0	1	(7)
Other	0		(5)	(3)	(10)
Total increase (decrease)	(12)		(49)	(11)	(159)
Total income taxes	103		116	362	321
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities				(39)	3
LKE [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Deferred Income Tax Expense (Benefit)		$ 9
LGE [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities		16
KU [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities		19
LG And E And KU Energy LLC [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	34		74	97	181
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	6		8	17	19
Amortization of investment tax credit	(1)		(1)	(3)	(2)
Deferred tax impact of U.S. tax reform	(2)		0	(2)	0
Amortization of excess deferred income taxes	(3)		0	(14)	0
Deferred tax impact of state tax reform	0		0	9	0
Other	(2)		(2)	(2)	(3)
Total increase (decrease)	(2)		5	5	14
Total income taxes	32		79	102	195
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities				(62)	3
LG And E And KU Energy LLC [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Deferred Income Tax Expense (Benefit)		9
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities		16
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities		19
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	30		56	93	144
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	12		9	35	26
Depreciation and other items not normalized	(1)		(1)	(4)	(5)
Amortization of excess deferred income taxes	(5)		0	(13)	0
Stock-based compensation	0		0	0	(5)
Other	(1)		0	0	(1)
Total increase (decrease)	5		8	18	15
Total income taxes	35		64	111	159
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities				25	0
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	18		36	50	91
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	3		4	9	10
Amortization of excess deferred income taxes	(1)		0	(6)	0
Other	(2)		(1)	(2)	(2)
Total increase (decrease)	0		3	1	8
Total income taxes	18		39	51	99
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities				(24)	2
Louisville Gas And Electric Co [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities		16
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	21		43	60	111
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	3		5	10	11
Amortization of excess deferred income taxes	(2)		0	(8)	0
Other	(1)		(1)	(3)	(2)
Total increase (decrease)	0		4	(1)	9
Total income taxes	$ 21		$ 47	59	120
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities				$ (38)	$ 1
Kentucky Utilities Co [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities		$ 19

Income Taxes - Tax Reform (Deta

Income Taxes - Tax Reform (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 103	$ 116	$ 362	$ 321
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Income Tax Expense (Benefit)	321		321
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Income Tax Expense (Benefit)	321		321
Tax Cuts And Jobs Act [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Income Tax Expense (Benefit)	0		0
Tax Cuts And Jobs Act [Member] | Deemed Dividend [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	397		397
Income Tax Expense (Benefit)	139		139
Tax Cuts And Jobs Act [Member] | Deemed Dividend [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	462		462
Income Tax Expense (Benefit)	161		161
Tax Cuts And Jobs Act [Member] | Deemed Dividend [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(65)		(65)
Income Tax Expense (Benefit)	(22)		(22)
Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(67)		(67)
Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(67)		(67)
Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(330)		(330)
Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(462)		(462)
Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	132		132
Tax Cuts And Jobs Act [Member] | Foreign Tax Credit [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	(157)		(157)
Tax Cuts And Jobs Act [Member] | Foreign Tax Credit [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	(205)		(205)
Tax Cuts And Jobs Act [Member] | Foreign Tax Credit [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	48		48
Tax Cuts And Jobs Act [Member] | Valuation Of Foreign Tax Credit Carryforward [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	110		110
Tax Cuts And Jobs Act [Member] | Valuation Of Foreign Tax Credit Carryforward [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	145		145
Tax Cuts And Jobs Act [Member] | Valuation Of Foreign Tax Credit Carryforward [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	(35)		(35)
Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	229		229
Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	220		220
Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	9		9
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(107)		(107)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(105)		(105)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(2)		(2)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(39)		(39)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(39)		(39)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(68)		(68)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(105)		(105)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	37		37
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	(13)		(13)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	(13)		(13)
PPL Electric [Member] | Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	0		0
LG And E And KU Energy LLC [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	32	79	102	195
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)		(60)
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)		(45)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(15)		(15)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(28)		(28)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(28)		(28)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(32)		(32)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(45)		(45)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	13		13
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	110		110
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	112		112
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Reduction In U.S. Federal Income Tax Rate [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	(2)		(2)
Louisville Gas And Electric Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	18	39	51	99
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		0
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		0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(17)		(17)
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(17)		(17)
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	17		17
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	17		17
Kentucky Utilities Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	21	$ 47	59	$ 120
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(11)		(11)
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Bonus Depreciation [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	(11)		(11)
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	11		11
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	0		0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member] | September 30, 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)	$ 11		$ 11

Utility Rate Regulation - Regul

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Regulatory Assets [Line Items]
Current regulatory assets	$ 29	$ 34
Noncurrent regulatory assets	1,525	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
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	16	15
Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	4
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	847	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	45	33
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	47	54
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	18	26
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	88	92
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	190	173
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	267	234
Act 129 Compliance Rider [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	12	0
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	1
Noncurrent regulatory assets	8	9
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	18	16
Noncurrent regulatory assets	738	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] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	16	15
PPL Electric Utilities Corp [Member] | Plant outage costs [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] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	486	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	23	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	190	173
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [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	12	0
PPL Electric Utilities Corp [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	2	1
Noncurrent regulatory assets	2	0
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current regulatory assets	11	18
Noncurrent regulatory assets	787	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] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	4
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	361	376
LG And E And KU Energy LLC [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	23	33
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	24	25
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	18	26
LG And E And KU Energy LLC [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	88	92
LG And E And KU Energy LLC [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	267	234
LG And E And KU Energy LLC [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	5
Noncurrent regulatory assets	6	9
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	11	12
Noncurrent regulatory assets	400	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] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	4
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	227	234
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	12	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	18	26
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	52	54
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	74	61
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	5
Noncurrent regulatory assets	2	2
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	6
Noncurrent regulatory assets	387	384
Kentucky Utilities Co [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	6
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	134	142
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	11	15
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	9	9
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	36	38
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	193	173
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent regulatory assets	$ 4	$ 7

Utility Rate Regulation - Reg_2

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 136	$ 95
Noncurrent regulatory liabilities	2,739	2,704
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	35	34
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	9
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	22	1
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	23	26
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	9
Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	3
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	26	0
Noncurrent regulatory liabilities	41	0
Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	8
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	678	677
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	62	68
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,846	1,853
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	33	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	9	5
Noncurrent regulatory liabilities	7	5
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	72	86
Noncurrent regulatory liabilities	686	668
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	35	34
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	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	23	26
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	9
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	41	0
PPL Electric Utilities Corp [Member] | Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	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 OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	642	668
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	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	3	0
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	64	9
Noncurrent regulatory liabilities	2,053	2,036
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	22	1
LG And E And KU Energy LLC [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	3
LG And E And KU Energy LLC [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	3
LG And E And KU Energy LLC [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	26	0
LG And E And KU Energy LLC [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	678	677
LG And E And KU Energy LLC [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	62	68
LG And E And KU Energy LLC [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,204	1,185
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	33	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	7	2
Noncurrent regulatory liabilities	4	5
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	26	3
Noncurrent regulatory liabilities	920	919
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	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]
Current regulatory liabilities	2	3
Louisville Gas And Electric Co [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	12	0
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	280	282
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	43	47
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	560	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	1	0
Noncurrent regulatory liabilities	1	1
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	38	6
Noncurrent regulatory liabilities	1,133	1,117
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	1
Kentucky Utilities Co [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	3
Kentucky Utilities Co [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	0
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	398	395
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	19	21
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	644	633
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	33	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	6	2
Noncurrent regulatory liabilities	$ 3	$ 4

Utility Rate Regulation - Reg_3

Utility Rate Regulation - Regulatory Matters (Details) - USD ($) $ in Millions	Sep. 28, 2018	Jun. 14, 2018	Mar. 28, 2018	Mar. 20, 2018	Jan. 10, 2018	Aug. 31, 2016	Sep. 30, 2018	May 17, 2018
Pennsylvania Public Utility Commission [Member] | Remaining [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		$ 33
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		33
PPL Electric [Member] | Pennsylvania Public Utility Commission [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		$ 72
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Negative Surcharge								0.56%
Amended Negative Surcharge		7.05%
Approved Amount Of Rate Reduction Due To TCJA		$ 72
PPL Electric [Member] | Pennsylvania Public Utility Commission [Member] | Current [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		39
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		39
LKE [Member]
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers							$ 22
LKE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Additional Amount Of Rate Reduction Due To TCJA			$ 27
Approved Additional Amount Of Rate Reduction Due To TCJA	$ 13
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Return on Equity, Percentage	10.42%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 35
Public Utilities, Requested Rate Increase (Decrease), Percentage	3.00%
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service					$ 166
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			79
Approved Amount Of Rate Reduction Due To TCJA	$ 74
Interim Rate Reduction Due To TCJA, Amount			69
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	74
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			20
Approved Amount Of Rate Reduction Due To TCJA	20
Interim Rate Reduction Due To TCJA, Amount			20
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	20
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			59
Approved Amount Of Rate Reduction Due To TCJA	54
Interim Rate Reduction Due To TCJA, Amount			49
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	54
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 25
Public Utilities, Requested Rate Increase (Decrease), Percentage	7.50%
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member] | Substantially All Through Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 16
Interim Rate Reduction Due To TCJA, Amount			17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 16
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Return on Equity, Percentage	10.42%
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 112
Public Utilities, Requested Rate Increase (Decrease), Percentage	6.90%
Regulatory Matters - Kentucky Activities - CPCN and ECR 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 [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			108
Approved Amount Of Rate Reduction Due To TCJA	$ 101
Interim Rate Reduction Due To TCJA, Amount			91
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	101
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			21
Approved Amount Of Rate Reduction Due To TCJA	21
Interim Rate Reduction Due To TCJA, Amount			21
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	21
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			87
Approved Amount Of Rate Reduction Due To TCJA	80
Interim Rate Reduction Due To TCJA, Amount			70
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	80
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		$ 72
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Negative Surcharge								0.56%
Amended Negative Surcharge		7.05%
Approved Amount Of Rate Reduction Due To TCJA		$ 72
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Current [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		39
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		39
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Remaining [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		33
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		$ 33
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 [Abstract]
Suspended Additional Amount Of Rate Reduction Due To TCJA			27
Approved Additional Amount Of Rate Reduction Due To TCJA	$ 13
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]
Public Utilities, Requested Return on Equity, Percentage	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]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 35
Public Utilities, Requested Rate Increase (Decrease), Percentage	3.00%
Regulatory Matters - Kentucky Activities - CPCN and ECR 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] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			79
Approved Amount Of Rate Reduction Due To TCJA	$ 74
Interim Rate Reduction Due To TCJA, Amount			69
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	74
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			20
Approved Amount Of Rate Reduction Due To TCJA	20
Interim Rate Reduction Due To TCJA, Amount			20
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	20
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			59
Approved Amount Of Rate Reduction Due To TCJA	54
Interim Rate Reduction Due To TCJA, Amount			49
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	54
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]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 25
Public Utilities, Requested Rate Increase (Decrease), Percentage	7.50%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member] | Substantially All Through Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 16
Interim Rate Reduction Due To TCJA, Amount			17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 16
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Return on Equity, Percentage	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]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 112
Public Utilities, Requested Rate Increase (Decrease), Percentage	6.90%
Regulatory Matters - Kentucky Activities - CPCN and ECR 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 [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			108
Approved Amount Of Rate Reduction Due To TCJA	$ 101
Interim Rate Reduction Due To TCJA, Amount			91
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	101
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			21
Approved Amount Of Rate Reduction Due To TCJA	21
Interim Rate Reduction Due To TCJA, Amount			21
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	21
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			87
Approved Amount Of Rate Reduction Due To TCJA	80
Interim Rate Reduction Due To TCJA, Amount			70
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 80
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company And Kentucky Utilities [Member]
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers							22
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 - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers							22
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Return on Equity, Percentage	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]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 35
Public Utilities, Requested Rate Increase (Decrease), Percentage	3.00%
Regulatory Matters - Kentucky Activities - CPCN and ECR 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 Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Additional Amount Of Rate Reduction Due To TCJA			10
Suspended Amount Of Rate Reduction Due To TCJA			79
Approved Amount Of Rate Reduction Due To TCJA	$ 74
Approved Additional Amount Of Rate Reduction Due To TCJA	6
Interim Rate Reduction Due To TCJA, Amount			69
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	74
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			20
Approved Amount Of Rate Reduction Due To TCJA	20
Interim Rate Reduction Due To TCJA, Amount			20
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	20
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA			59
Approved Amount Of Rate Reduction Due To TCJA	54
Interim Rate Reduction Due To TCJA, Amount			49
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	54
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 25
Public Utilities, Requested Rate Increase (Decrease), Percentage	7.50%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member] | Substantially All Through Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 16
Interim Rate Reduction Due To TCJA, Amount			17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 16
Kentucky Utilities Co [Member]
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers							$ 22
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Return on Equity, Percentage	10.42%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 112
Public Utilities, Requested Rate Increase (Decrease), Percentage	6.90%
Regulatory Matters - Kentucky Activities - CPCN and ECR 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 [Abstract]
Suspended Additional Amount Of Rate Reduction Due To TCJA			17
Suspended Amount Of Rate Reduction Due To TCJA				$ 108
Approved Amount Of Rate Reduction Due To TCJA	$ 101
Approved Additional Amount Of Rate Reduction Due To TCJA	7
Interim Rate Reduction Due To TCJA, Amount			91
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	101
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA				21
Approved Amount Of Rate Reduction Due To TCJA	21
Interim Rate Reduction Due To TCJA, Amount			21
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	21
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - TCJA [Abstract]
Suspended Amount Of Rate Reduction Due To TCJA				$ 87
Approved Amount Of Rate Reduction Due To TCJA	80
Interim Rate Reduction Due To TCJA, Amount			$ 70
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 80

Utility Rate Regulation - Other

Utility Rate Regulation - Other (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of Accounts Receivable	$ 334	$ 324	$ 1,000	$ 968
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of Accounts Receivable	$ 334	$ 324	$ 1,000	$ 968

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)	Oct. 31, 2018USD ($)	Sep. 30, 2018GBP (£)	Dec. 31, 2017USD ($)	Dec. 31, 2017GBP (£)
UNITED KINGDOM
Line of Credit Facility [Line Items]
Capacity | £			£ 1,315
Borrowed | £			427		£ 448
Letters of Credit and Commercial Paper Issued | £			4		4
Unused Capacity	$ 1,100		882
UNITED KINGDOM | Uncommitted Credit Facilities [Member]
Line of Credit Facility [Line Items]
Capacity | £			130
Borrowed | £			0		0
Letters of Credit and Commercial Paper Issued | £			4		4
Unused Capacity | £			126
WPD PLC [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity | £			210
Borrowed	$ 200		154	$ 200	148
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 54
Interest rate on outstanding borrowing	2.90%		2.90%	2.17%	2.17%
Borrowings | £			£ 156
WPD PLC [Member] | UNITED KINGDOM | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Dec. 31, 2018
Capacity | £			130
Borrowed	$ 168		130		£ 0
Letters of Credit and Commercial Paper Issued | £			0		0
Unused Capacity | £			£ 0
Interest rate on outstanding borrowing	1.97%		1.97%
WPD South West [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jul. 31, 2021
Capacity | £			£ 245
Borrowed | £			0		0
Letters of Credit and Commercial Paper Issued | £			0		0
Unused Capacity | £			245
WPD East Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jul. 31, 2021
Capacity | £			300
Borrowed	$ 121		93	$ 244	180
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 207
Interest rate on outstanding borrowing	1.09%		1.09%	0.89%	0.89%
WPD West Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jul. 31, 2021
Capacity | £			£ 300
Borrowed	$ 65		50	$ 162	£ 120
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 250
Interest rate on outstanding borrowing	1.12%		1.12%	0.89%	0.89%
PPL Capital Funding [Member] | UNITED STATES
Line of Credit Facility [Line Items]
Capacity	$ 1,350
Borrowed	0			$ 0
Letters of Credit and Commercial Paper Issued	711			248
Unused Capacity	$ 639
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 950
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	691			230
Unused Capacity	$ 259
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Nov. 30, 2018
Capacity	$ 300
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	0			0
Unused Capacity	$ 300
PPL Capital Funding [Member] | UNITED STATES | Bilateral Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Mar. 31, 2019
Capacity	$ 100
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	20			18
Unused Capacity	$ 80
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 650
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	1			1
Unused Capacity	$ 649
LKE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2018
Capacity	$ 75
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	0			0
Unused Capacity	75
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	700
Borrowed	200			100
Letters of Credit and Commercial Paper Issued	176			199
Unused Capacity	$ 324
LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	176			199
Unused Capacity	$ 324
LGE [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200			100
Letters of Credit and Commercial Paper Issued	0			0
Unused Capacity	0
KU [Member]
Line of Credit Facility [Line Items]
Capacity	598
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	326			243
Unused Capacity	$ 272
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	128			45
Unused Capacity	$ 272
KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	198			198
Unused Capacity	$ 0
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 650
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	1			1
Unused Capacity	$ 649
LG And E And KU Energy LLC [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2018
Capacity	$ 75
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	0			0
Unused Capacity	75
LG And E And KU Energy LLC [Member] | LGE [Member]
Line of Credit Facility [Line Items]
Capacity	700
Borrowed	200			100
Letters of Credit and Commercial Paper Issued	176			199
Unused Capacity	$ 324
LG And E And KU Energy LLC [Member] | LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	176			199
Unused Capacity	$ 324
LG And E And KU Energy LLC [Member] | LGE [Member] | Term Loan Facility [Member]
Line of Credit Facility [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]
Line of Credit Facility [Line Items]
Capacity	598
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	326			243
Unused Capacity	$ 272
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	128			45
Unused Capacity	$ 272
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	198			198
Unused Capacity	0
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	700
Borrowed	200			100
Letters of Credit and Commercial Paper Issued	176			199
Unused Capacity	$ 324
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	176			199
Unused Capacity	$ 324
Louisville Gas And Electric Co [Member] | Term Loan Facility [Member]
Line of Credit Facility [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]
Line of Credit Facility [Line Items]
Capacity	598
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	326			243
Unused Capacity	$ 272
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	128			45
Unused Capacity	$ 272
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0			0
Letters of Credit and Commercial Paper Issued	198			$ 198
Unused Capacity	0
PPL Energy Funding [Member] | PPL Electric Utilities Corp [Member]
Line of Credit Facility [Line Items]
Intercompany Note Affiliate Maximum Borrowing Capacity Increase	250
Intercompany note with affiliate maximum borrowing capacity	650
PPL Energy Funding [Member] | LG And E And KU Energy LLC [Member]
Line of Credit Facility [Line Items]
Intercompany note with affiliate maximum borrowing capacity	$ 300
PPL Energy Funding [Member] | LG And E And KU Energy LLC [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Intercompany Note Affiliate Maximum Borrowing Capacity Increase		$ 75
Intercompany note with affiliate maximum borrowing capacity		$ 375

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Short-term Debt [Line Items]
Capacity	$ 2,350
Commercial Paper Issuances	995	$ 474
Unused Capacity	$ 1,355
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.38%	1.64%
Capacity	$ 1,000
Commercial Paper Issuances	691	$ 230
Unused Capacity	$ 309
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	2.34%	1.83%
Capacity	$ 350
Commercial Paper Issuances	176	$ 199
Unused Capacity	$ 174
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.97%
Capacity	$ 350
Commercial Paper Issuances	128	$ 45
Unused Capacity	$ 222
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	2.34%	1.83%
Capacity	$ 350
Commercial Paper Issuances	176	$ 199
Unused Capacity	$ 174
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.97%
Capacity	$ 350
Commercial Paper Issuances	128	$ 45
Unused Capacity	$ 222
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.83%
Capacity	$ 350
Commercial Paper Issuances	176	$ 199
Unused Capacity	$ 174
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.97%
Capacity	$ 350
Commercial Paper Issuances	128	$ 45
Unused Capacity	$ 222

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) £ in Millions, $ in Millions	1 Months Ended						3 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 (£)	May 31, 2018GBP (£)	Mar. 31, 2018GBP (£)
WPD PLC [Member] | Senior Notes [Member] | Subsequent Event [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £		£ 350
Stated interest rate		3.50%
Proceeds from debt, net of issuance costs | £		£ 346
Maturity date	Dec. 31, 2026	Dec. 31, 2026
Proceeds from debt, including premium net of debt issuance costs	$ 456
WPD South Wales PLC [Member] | Index Linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £										£ 30
Stated interest rate						0.01%	0.01%			0.01%
Proceeds from debt, net of issuance costs | £								£ 31
Maturity date							Dec. 31, 2036	Dec. 31, 2036
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%
Proceeds from debt, net of issuance costs | £					£ 31
Maturity date				Dec. 31, 2028	Dec. 31, 2028
Proceeds from debt, including premium net of debt issuance costs				$ 41
PPL Electric [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 400
Stated interest rate			4.15%
Proceeds from debt, net of issuance costs			$ 394
Maturity date			Dec. 31, 2048
PPL Capital Funding [Member] | Senior Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 250
Stated interest rate			1.90%
LGE [Member] | Senior Debt Obligations [Member] | 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						Dec. 31, 2026
Repurchase date of debt instruments						Sep. 1, 2021
LGE [Member] | Senior Debt Obligations [Member] | 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				Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments				May 3, 2021	May 3, 2021
LGE [Member] | Senior Debt Obligations [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				Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments				May 3, 2021	May 3, 2021
PPL Electric Utilities Corp [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 400
Stated interest rate			4.15%
Proceeds from debt, net of issuance costs			$ 394
Maturity date			Dec. 31, 2048
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Debt Obligations [Member] | 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						Dec. 31, 2026
Repurchase date of debt instruments						Sep. 1, 2021
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Debt Obligations [Member] | 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				Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments				May 3, 2021	May 3, 2021
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Debt Obligations [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				Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments				May 3, 2021	May 3, 2021
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member] | Note Payable [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate				4.00%					4.00%
Maturity date				May 31, 2028	May 31, 2028
Notes Payable, Noncurrent				$ 250
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 28	$ 28
Stated interest rate						2.30%	2.30%			2.30%
Maturity date						Dec. 31, 2026
Repurchase date of debt instruments						Sep. 1, 2021
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | 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				Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments				May 3, 2021	May 3, 2021
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [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				Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments				May 3, 2021	May 3, 2021

Financing Activities - Equity S

Financing Activities - Equity Securities (Details) $ / shares in Units, $ in Millions		1 Months Ended		9 Months Ended
		Sep. 30, 2018USD ($)shares	May 31, 2018counterpartiesshares	Sep. 30, 2018USD ($)$ / sharesshares	Sep. 30, 2017USD ($)shares	Feb. 28, 2018USD ($)
Equity Programs [Line Items]
Issuance of common stock | $				$ 678	$ 275
Common Stock [Member]
Equity Programs [Line Items]
Common stock issued	[1]			26,304,000	8,402,000
Forward Sale Agreement [Member] | Common Stock [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares			55,000,000
Number of Counterparties | counterparties			2
Total Number Of Shares Issued In Forward Sales Agreements And Overallotment Option			63,250,000
Sale of Stock, Price Per Share | $ / shares				$ 26.7057
Common stock issued		20,000,000
Issuance of common stock | $		$ 520
Over-Allotment Option [Member] | Forward Sale Agreement [Member] | Common Stock [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares			8,250,000
Maximum [Member] | Forward Sale Agreement [Member] | Common Stock [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%
Common stock issued				4,200,000
Issuance of common stock | $				$ 119
[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 (Details) - $ / shares	1 Months Ended	3 Months Ended		9 Months Ended
	Aug. 31, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Distributions (Numeric) [Abstract]
Dividend payable date of quarterly common stock dividend	Oct. 1, 2018
Current quarterly common stock dividend (in dollars per share)	$ 41	$ 0.41	$ 0.395	$ 1.23	$ 1.185
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.64

Defined Benefits (Details)

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Pension Plan [Member] | U.S.
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	$ 15	$ 17	$ 46	$ 49
Interest cost	39	42	117	126
Expected return on plan assets	(62)	(58)	(186)	(173)
Amortization of: [Abstract]
Prior service cost	2	2	7	7
Actuarial loss	22	18	63	52
Net periodic defined benefit costs (credits) before settlements and special termination benefits	16	21	47	61
Settlements	0	1	0	1
Net periodic defined benefit costs (credits)	16	22	47	63
Special termination benefits	0	0	$ 0	1
Collective Bargaining Agreement Term			5 years
Pension Plan [Member] | U.S. | Qualified Plan [Member]
Amortization of: [Abstract]
Settlements	1	5	$ 5	5
Pension Plan [Member] | U.K.
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	21	20	63	57
Interest cost	46	45	140	132
Expected return on plan assets	(145)	(130)	(445)	(382)
Amortization of: [Abstract]
Prior service cost	0	0	0	0
Actuarial loss	37	36	114	107
Net periodic defined benefit costs (credits) before settlements and special termination benefits	(41)	(29)	(128)	(86)
Settlements	0	0	0	0
Net periodic defined benefit costs (credits)	(41)	(29)	(128)	(86)
Special termination benefits	0	0	0	0
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	2	5	6
Interest cost	5	5	15	17
Expected return on plan assets	(4)	(6)	(17)	(17)
Amortization of: [Abstract]
Prior service cost	0	0	0	(1)
Actuarial loss	0	1	0	1
Net periodic defined benefit costs (credits)	2	2	3	6
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	5	6	12	19
LG And E And KU Energy LLC [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	6	6	18	18
Interest cost	16	17	48	51
Expected return on plan assets	(25)	(23)	(76)	(69)
Amortization of: [Abstract]
Prior service cost	3	2	7	6
Actuarial loss	$ 8	$ 8	$ 26	$ 23
Regulatory Asset Amortization Period	15 years	15 years	15 years	15 years
Net periodic defined benefit costs (credits)	$ 8	$ 10	$ 23	$ 29
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	2	3	8	8
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. | Qualified Plan [Member]
Amortization of: [Abstract]
Settlements	1	5	5	5
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	3	3
Interest cost	2	2	6	6
Expected return on plan assets	(2)	(2)	(6)	(5)
Amortization of: [Abstract]
Prior service cost	0	1	1	1
Actuarial loss	0	0	(1)	0
Net periodic defined benefit costs (credits)	1	2	3	5
Louisville Gas And Electric Co [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	1	3	5	8
Louisville Gas And Electric Co [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	0	0	1	1
Interest cost	3	3	9	9
Expected return on plan assets	(6)	(5)	(17)	(16)
Amortization of: [Abstract]
Prior service cost	1	1	4	3
Actuarial loss	2	$ 3	$ 5	$ 7
Regulatory Asset Amortization Period		15 years	15 years	15 years
Net periodic defined benefit costs (credits)	0	$ 2	$ 2	$ 4
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		1	1	3
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. | Qualified Plan [Member]
Amortization of: [Abstract]
Settlements	1	5	$ 5	5
Kentucky Utilities Co [Member]
Amortization of: [Abstract]
Collective Bargaining Agreement Term			3 years
Kentucky Utilities Co [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	$ 1	$ 2	$ 3	$ 7

Commitments and Contingencies -

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details) $ in Millions	Oct. 29, 2018USD ($)	Sep. 30, 2018claimresidentcoal-fired_unitmi
Subsequent Event [Member]
Claim By Former Affiliate [Abstract]
Percent of ownership of Talen Energy by Riverstone	35.00%
Amount of alleged improper distribution | $	$ 733
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		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		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		3
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		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		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		3
Louisville Gas And Electric Co [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident		6
Number of miles within plant that would include a class of residents		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		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		3

Commitments and Contingencies_2

Commitments and Contingencies - Environmental Matters and Other (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)employees	Dec. 31, 2017USD ($)
PPL Electric [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Separation Benefits | $	$ 6
Number Of Employees Displaced | employees	86
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]
Separation Benefits | $	$ 6
Number Of Employees Displaced | employees	86
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]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees | employees	68
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees | employees	68

Commitments and Contingencies_3

Commitments and Contingencies - Guarantees and Other Assurances (Details) $ in Millions	9 Months Ended
	Sep. 30, 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 estimable	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 and Sales Of Assets [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 10
Expiration date	2,020
Minimum Period In Years That Indemnifications Generally Expire | Integer	2
Maximum Period In Years That Indemnifications Generally Expire | 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	$ 81
PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 15
Expiration date	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
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LKE Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 114
PPL Electric Utilities Corp [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 15
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 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
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]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 114
Louisville Gas And Electric Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 79
Kentucky Utilities Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 35

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended
	May 31, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Oct. 31, 2018
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant		$ 14	$ 43	$ 45	$ 138
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant		34	15	110	48
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity		650		650
Notes receivable from affiliate		0		0		$ 0
Intercompany Note Affiliate Maximum Borrowing Capacity Increase		250		250
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates		80		80		225
Long-term debt to affiliate		650		650		400
Interest Expense with Affiliate		7	5	18	13
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant		5	4	19	15
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity		300		300
Notes payable to affiliates		80		$ 80		$ 225
Intercompany borrowings demand note rate on outstanding borrowing				3.61%		2.87%
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member] | Subsequent Event [Member]
Intercompany Borrowings (Numeric) [Abstract]
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]
Intercompany note with affiliate maximum borrowing capacity		300		$ 300
Notes Receivable, Related Parties, Noncurrent		0		$ 0		$ 0
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Debt instrument term (in years)				10 years
Long-term debt to affiliate		$ 400		$ 400
Interest rate on ten-year note		3.50%		3.50%
Interest Expense with Affiliate		$ 4	4	$ 11	11
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member]
Intercompany Borrowings (Numeric) [Abstract]
Interest Expense with Affiliate		3		4
LG And E And KU Energy LLC [Member] | Note Payable [Member] | Affiliated Entity [Member]
Intercompany Borrowings (Numeric) [Abstract]
Stated interest rate	4.00%
Maturity date	May 31, 2028
Notes Payable, Noncurrent	$ 250
Louisville Gas And Electric Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates		36	38	113	120
Kentucky Utilities Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates		$ 42	$ 43	$ 127	$ 134

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Other Income
Economic foreign currency exchange contracts	$ 40	$ (81)	$ 92	$ (237)
Defined benefit plans - non-service credits	61	41	195	123
Interest Income	3	1	5	2
AFUDC - equity component	5	5	15	11
Miscellaneous	2	2	3	11
Total Other Income	111	(32)	310	(90)
Other Expense
Charitable Contributions	1	1	6	6
Miscellaneous	4	2	7	16
Total Other Expense	5	3	13	22
Other Income (Expense) - net	106	(35)	297	(112)
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	1	0	4	0
AFUDC - equity component	5	5	15	11
Miscellaneous	0	0	1	0
Total Other Income	6	5	20	11
Other Expense
Charitable Contributions	1	1	2	2
Miscellaneous	0	0	0	1
Total Other Expense	1	1	2	3
Other Income (Expense) - net	$ 5	$ 4	$ 18	$ 8

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents	$ 842	$ 485
Restricted cash and cash equivalents	22	26
Special use funds	63	0
Price risk management assets:
Foreign currency contracts	174	163
Cross-currency swaps	123	101
Total price risk management assets	297	264
Total Assets	1,224	775
Price risk management liabilities:
Interest rate swaps	19	26
Foreign currency contracts	30	148
Total price risk management liabilities	49	174
Level 1 [Member]
Assets
Cash and cash equivalents	842	485
Restricted cash and cash equivalents	22	26
Special use funds	63	0
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total Assets	927	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	174	163
Cross-currency swaps	123	101
Total price risk management assets	297	264
Total Assets	297	264
Price risk management liabilities:
Interest rate swaps	19	26
Foreign currency contracts	30	148
Total price risk management liabilities	49	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	414	49
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total Assets	416	51
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	414	49
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total Assets	416	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	29	30
Price risk management assets:
Total Assets	29	30
Price risk management liabilities:
Interest rate swaps	19	26
Total price risk management liabilities	19	26
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	29	30
Price risk management assets:
Total Assets	29	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	19	26
Total price risk management liabilities	19	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	11	15
Price risk management assets:
Total Assets	11	15
Price risk management liabilities:
Interest rate swaps	19	26
Total price risk management liabilities	19	26
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	11	15
Price risk management assets:
Total Assets	11	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	19	26
Total price risk management liabilities	19	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	18	15
Price risk management assets:
Total Assets	18	15
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	18	15
Price risk management assets:
Total Assets	18	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 - Finan

Fair Value Measurements - Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 20,254	$ 20,195
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	23,023	23,783
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,693	3,298
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,899	3,769
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	5,501	5,159
LG And E And KU Energy LLC [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	5,783	5,670
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,808	1,709
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,879	1,865
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	2,320	2,328
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 2,467	$ 2,605

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 25	$ 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 Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2018GBP (£)
Cash Flow Hedges [Member] | Cross Currency Interest Rate Swap Contracts [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	$ 0
Notional amount	702		$ 702
Cash Flow Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
No or insignificant after-tax gains (losses) previously recorded in AOCI reclassified to earnings related to interest rate cash flow hedge contracts			For the three and nine months ended September 30, 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and nine months ended September 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.
No or insignificant unrealized after-tax gains (losses) on interest rate cash flow hedge contracts expected to be reclassified into earnings during next 12 months			insignificant
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	0	$ 0	$ 0	$ 0
Notional amount	97		$ 97			£ 75
Derivative, Maturity Date			Dec. 31, 2026
Net Investment Hedges [Member] | Combined Foreign Currency Contracts And Intercompany Loans [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			$ 30		$ 22
Economic Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Minimum Termination Date Net Investment Hedges Classified As Economic Activity			Oct. 31, 2018
Maximum Termination Date Net Investment Hedges Classified As Economic Activity			Oct. 31, 2020
Total exposure hedged related to foreign currency contracts for anticipated earnings hedges classified as economic activity	2,500		$ 2,500			£ 1,800
LGE [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Notional amount	147		$ 147
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2,033
LG And E And KU Energy LLC [Member] | LGE [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Notional amount	147		$ 147
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2,033
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Notional amount	$ 147		$ 147
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
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	Sep. 30, 2018	Dec. 31, 2017
Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 123	$ 101
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	4
Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	4
Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	118	97
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	118	97
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	174	163
Liability value	49	174
Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	86	45
Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	86	45
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	88	118
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	88	118
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	26	71
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	4
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	22	67
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	23	103
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	15	22
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	8	81
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	19	26
LG And E And KU Energy LLC [Member] | 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] | 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] | 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] | 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] | 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] | 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] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	15	22
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	15	22
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	19	26
Louisville Gas And Electric Co [Member] | 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] | 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] | 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] | 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] | 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] | 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] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	15	22
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	$ 15	$ 22

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Cash Flow Hedges [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	$ 17	$ 1	$ 25	$ (29)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	(1)
Cash Flow Hedges [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	27	1	26	(36)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	0	0	0	(2)
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 (Effective Portion)	(2)	(2)	(6)	(6)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	(1)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	27	1	26	(34)
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 (Effective Portion)	1	1	1	1
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	0
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 (Effective Portion)	18	2	30	(24)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	0
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	0	1	11	1
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	39	(82)	88	(241)
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	40	(81)	92	(237)
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	2	1	7	2
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	(1)	(1)	(4)	(4)
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	2	1	7	2
LG And E And KU Energy LLC [Member] | 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	(1)	(1)	(4)	(4)
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	2	1	7	2
Louisville Gas And Electric Co [Member] | 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	$ (1)	$ (1)	$ (4)	$ (4)

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Sep. 30, 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	$ 8
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	8
Treasury Derivatives [Member]
Assets [Abstract]
Gross	297	$ 264
Derivative instruments - eligible for offset	28	107
Cash collateral received - eligible for offset	25	20
Net	244	137
Liabilities [Abstract]
Gross	49	174
Derivative instruments - eligible for offset	28	107
Cash collateral pledged - eligible for offset	0	0
Net	21	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]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross	19	26
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	19	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]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross	19	26
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 19	$ 26

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 397
Accretion	14
Obligations incurred	8
Effect of foreign exchange rates	(2)
Changes in estimated timing or cost	(6)
Obligations settled	(46)
Balance at End of Period	365
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	356
Accretion	13
Obligations incurred	8
Effect of foreign exchange rates	0
Changes in estimated timing or cost	(14)
Obligations settled	(46)
Balance at End of Period	317
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	121
Accretion	5
Obligations incurred	0
Effect of foreign exchange rates	0
Changes in estimated timing or cost	(2)
Obligations settled	(17)
Balance at End of Period	107
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	235
Accretion	8
Obligations incurred	8
Effect of foreign exchange rates	0
Changes in estimated timing or cost	(12)
Obligations settled	(29)
Balance at End of Period	$ 210

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (3,495)	$ (3,523)	$ (3,422)	$ (3,778)
Amounts arising during the period	(173)	(14)	(310)	152
Reclassifications from accumulated other comprehensive income	20	34	84	123
Net other comprehensive income during the period	(153)	20	(226)	275
Balance at end of period	(3,648)	(3,503)	(3,648)	(3,503)
Foreign currency translation adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(1,223)	(1,420)	(1,089)	(1,627)
Amounts arising during the period	(187)	(12)	(321)	195
Reclassifications from accumulated other comprehensive income	0	0	0	0
Net other comprehensive income during the period	(187)	(12)	(321)	195
Balance at end of period	(1,410)	(1,432)	(1,410)	(1,432)
Unrealized gains (losses) on qualifying derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(21)	(13)	(13)	(7)
Amounts arising during the period	22	1	21	(29)
Reclassifications from accumulated other comprehensive income	(14)	0	(21)	24
Net other comprehensive income during the period	8	1	0	(5)
Balance at end of period	(13)	(12)	(13)	(12)
Equity investees' AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	0	0	0	(1)
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	0	0	0	1
Net other comprehensive income during the period	0	0	0	1
Balance at end of period	0	0	0	0
Defined benefit plans Prior service costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(7)	(7)	(7)	(8)
Amounts arising during the period	0	0	(1)	0
Reclassifications from accumulated other comprehensive income	0	0	1	1
Net other comprehensive income during the period	0	0	0	1
Balance at end of period	(7)	(7)	(7)	(7)
Defined benefit plans Actuarial gain (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(2,244)	(2,083)	(2,313)	(2,135)
Amounts arising during the period	(8)	(3)	(9)	(14)
Reclassifications from accumulated other comprehensive income	34	34	104	97
Net other comprehensive income during the period	26	31	95	83
Balance at end of period	(2,218)	(2,052)	(2,218)	(2,052)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(86)	(77)	(88)	(70)
Amounts arising during the period		(1)		(12)
Reclassifications from accumulated other comprehensive income	2	1	4	5
Net other comprehensive income during the period	2	0	4	(7)
Balance at end of period	(84)	(77)	(84)	(77)
LG And E And KU Energy LLC [Member] | Equity investees' AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	0	0	0	(1)
Amounts arising during the period		0		0
Reclassifications from accumulated other comprehensive income	0	0	0	1
Net other comprehensive income during the period	0	0	0	1
Balance at end of period	0	0	0	0
LG And E And KU Energy LLC [Member] | Defined benefit plans Prior service costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(8)	(7)	(9)	(8)
Amounts arising during the period		0		0
Reclassifications from accumulated other comprehensive income	1	0	2	1
Net other comprehensive income during the period	1	0	2	1
Balance at end of period	(7)	(7)	(7)	(7)
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 period	(78)	(70)	(79)	(61)
Amounts arising during the period		(1)		(12)
Reclassifications from accumulated other comprehensive income	1	1	2	3
Net other comprehensive income during the period	1	0	2	(9)
Balance at end of period	$ (77)	$ (70)	$ (77)	$ (70)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	$ 106	$ (35)	$ 297	$ (112)
Interest Expense	(244)	(230)	(718)	(669)
Income Taxes	(103)	(116)	(362)	(321)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(20)	(34)	(84)	(123)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	17	1	25	(30)
Income Taxes	(3)	(1)	(4)	6
Total After-tax	14	0	21	(24)
Qualifying Derivatives [Member] | Interest Rate Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	(2)	(2)	(6)	(7)
Qualifying Derivatives [Member] | Cross Currency Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	18	2	30	(24)
Interest Expense	1	1	1	1
Equity Investees Accumulated Other Comprehensive Income [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	0	0	0	(1)
Total Pre-tax	0	0	0	(1)
Income Taxes	0	0	0	0
Total After-tax	0	0	0	(1)
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	(43)	(45)	(132)	(127)
Income Taxes	9	11	27	29
Total After-tax	(34)	(34)	(105)	(98)
Defined Benefit Plans [Member] | Prior Service Costs [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	(1)	(1)	(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 [Line Items]
Total Pre-tax	$ (42)	$ (44)	$ (130)	$ (125)

New Accounting Guidance Pendi_2

New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Details) $ in Millions	Sep. 30, 2018USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Impact of Adoption of ASU 2018-02	$ 50
LG And E And KU Energy LLC [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Impact of Adoption of ASU 2018-02	$ 18