PPL Electric Utilities 10-Q 3 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Jul. 27, 2017
Document Entity Information [Line Items]
Document Type	10-Q
Document Period End Date	Jun. 30, 2017
Amendment Flag	false
Entity Registrant Name	PPL Corp
Entity Central Index Key	922,224
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		685,855,683
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	PPL ELECTRIC UTILITIES CORP
Entity Central Index Key	317,187
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		66,368,056
LG And E And KU Energy LLC [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LG&E & KU Energy LLC
Entity Central Index Key	1,518,339
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
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 Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		21,294,223
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	KENTUCKY UTILITIES CO
Entity Central Index Key	55,387
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		37,817,878

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Operating Revenues
Operating Revenues		$ 1,725	$ 1,785	$ 3,676	$ 3,796
Operation
Fuel		183	183	374	380
Energy purchases		136	147	351	380
Other operation and maintenance		388	425	820	875
Depreciation		246	231	488	460
Taxes, other than income		70	74	145	153
Total Operating Expenses		1,023	1,060	2,178	2,248
Operating Income		702	725	1,498	1,548
Other Income (Expense) - net		(112)	174	(159)	235
Interest Expense		222	224	439	448
Income Before Income Taxes		368	675	900	1,335
Income Taxes		76	192	205	371
Net Income		$ 292	$ 483	$ 695	$ 964
Net Income:
Basic (in dollars per share)		$ 0.43	$ 0.71	$ 1.02	$ 1.42
Diluted (in dollars per share)		0.43	0.71	1.01	1.41
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.3950	$ 0.38	$ 0.79	$ 0.76
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		683,841	677,145	682,370	676,293
Diluted (in shares)		686,351	680,729	684,725	679,773
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 500	$ 495	$ 1,073	$ 1,080
Operation
Energy purchases		107	118	253	285
Other operation and maintenance		138	137	302	287
Depreciation		76	62	151	121
Taxes, other than income		23	24	52	53
Total Operating Expenses		344	341	758	746
Operating Income		156	154	315	334
Other Income (Expense) - net		3	5	4	8
Interest Income from Affiliate		1	0	1	0
Interest Expense		36	32	69	65
Income Before Income Taxes		124	127	251	277
Income Taxes		47	48	95	104
Net Income	[1]	77	79	156	173
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		723	721	1,532	1,547
Operation
Fuel		183	182	374	380
Energy purchases		29	28	98	94
Other operation and maintenance		192	204	399	406
Depreciation		105	100	210	199
Taxes, other than income		16	15	32	30
Total Operating Expenses		525	529	1,113	1,109
Operating Income		198	192	419	438
Other Income (Expense) - net		(4)	(5)	(6)	(6)
Interest Expense		50	48	99	97
Interest Expense with Affiliate		4	4	8	8
Income Before Income Taxes		140	135	306	327
Income Taxes		53	51	116	123
Net Income		87	84	190	204
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		320	317	694	692
Electric revenue from affiliate		4	6	21	17
Operating Revenues		324	323	715	709
Operation
Fuel		69	69	149	147
Energy purchases		25	23	89	85
Energy purchases from affiliate		3	3	5	5
Other operation and maintenance		86	92	173	179
Depreciation		45	42	89	83
Taxes, other than income		9	7	17	15
Total Operating Expenses		237	236	522	514
Operating Income		87	87	193	195
Other Income (Expense) - net		1	(5)	(1)	(5)
Interest Expense		19	18	36	35
Income Before Income Taxes		69	64	156	155
Income Taxes		27	24	60	59
Net Income	[1]	42	40	96	96
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		403	404	838	855
Electric revenue from affiliate		3	3	5	5
Operating Revenues		406	407	843	860
Operation
Fuel		114	113	225	233
Energy purchases		4	5	9	9
Energy purchases from affiliate		4	6	21	17
Other operation and maintenance		100	107	209	213
Depreciation		61	58	121	116
Taxes, other than income		7	8	15	15
Total Operating Expenses		290	297	600	603
Operating Income		116	110	243	257
Other Income (Expense) - net		(2)	1	(3)	(1)
Interest Expense		24	23	48	47
Income Before Income Taxes		90	88	192	209
Income Taxes		34	34	73	80
Net Income	[2]	$ 56	$ 54	$ 119	$ 129
[1]	Net income equals comprehensive income.
[2]	Net income approximates comprehensive income.

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Net Income	$ 292	$ 483	$ 695	$ 964
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	231	268	207	(196)
Qualifying derivatives, net of tax	(24)	(85)	(30)	(5)
Defined benefit plans:
Net actuarial gain (loss), net of tax	(11)	2	(11)	2
Reclassifications from accumulated other comprehensive income (loss) - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	25	85	24	7
Equity investees' other comprehensive (income) loss, net of tax	1	(1)	1	(1)
Defined benefit plans:
Prior service costs, net of tax	1	1	1	1
Net actuarial (gain) loss, net of tax	31	32	63	63
Total other comprehensive income (loss)	254	302	255	(129)
Comprehensive income	546	785	950	835
LG And E And KU Energy LLC [Member]
Net Income	87	84	190	204
Defined benefit plans:
Net actuarial gain (loss), net of tax	(11)	1	(11)	1
Reclassifications from accumulated other comprehensive income (loss) - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax	0	(1)	1	(1)
Defined benefit plans:
Prior service costs, net of tax	1	1	1	1
Net actuarial (gain) loss, net of tax	1	1	2	2
Total other comprehensive income (loss)	(9)	2	(7)	3
Comprehensive income	$ 78	$ 86	$ 183	$ 207

CONDENSED CONSOLIDATED STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Tax effect of foreign currency translation adjustments arising during the period	$ 0	$ 0	$ (1)	$ (2)
Tax effect of qualifying derivatives arising during the period	5	22	7	7
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	7	(1)	7	(1)
Tax effect of qualifying derivatives reclassified from accumulated other comprehensive income (loss)	(7)	(21)	(7)	(2)
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	0	0	0
Tax effect of net actuarial (gain) loss reclassified from accumulated other comprehensive income (loss)	(9)	(8)	(18)	(17)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	7	(1)	7	(1)
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	0	0	0
Tax effect of net actuarial (gain) loss reclassified from accumulated other comprehensive income (loss)	$ (1)	$ (1)	$ (2)	$ (1)

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016
Cash Flows from Operating Activities
Net Income		$ 695	$ 964
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		488	460
Amortization		45	37
Defined benefit plans - expense (income)		(45)	(24)
Deferred income taxes and investment tax credits		201	320
Unrealized (gains) losses on derivatives, and other hedging activities		135	(192)
Stock-based compensation expense		22	18
Other		(5)	(11)
Change in current assets and current liabilities
Accounts receivable		26	16
Accounts payable		(92)	(39)
Unbilled revenues		70	(2)
Fuel, materials and supplies		42	21
Prepayments		(66)	(66)
Counterparty collateral		8	76
Taxes payable		(27)	22
Accrued interest		(77)	(85)
Other current liabilities		(52)	(47)
Other		(14)	(21)
Other operating activities
Defined benefit plans - funding		(552)	(224)
Other assets		(1)	2
Other liabilities		(11)	(55)
Net cash provided by operating activities		790	1,170
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,373)	(1,346)
Expenditures for intangible assets		(15)	(14)
Other investing activities		6	13
Net cash used in investing activities		(1,382)	(1,347)
Cash Flows from Financing Activities
Issuance of long-term debt		594	1,020
Retirement of long-term debt		(60)	(684)
Settlement of cross-currency swaps		0	46
Issuance of common stock		177	76
Payment of common stock dividends		(529)	(513)
Net increase (decrease) in short-term debt		554	(66)
Other financing activities		(25)	(31)
Net cash provided by (used in) financing activities		711	(152)
Effect of Exchange Rates on Cash and Cash Equivalents		7	(15)
Net Increase (Decrease) in Cash and Cash Equivalents		126	(344)
Cash and Cash Equivalents at Beginning of Period		341	836
Cash and Cash Equivalents at End of Period		467	492
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		284	283
Accrued expenditures for intangible assets at June 30,		56	94
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net Income	[1]	156	173
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		151	121
Amortization		15	15
Defined benefit plans - expense (income)		7	7
Deferred income taxes and investment tax credits		84	107
Other		(4)	(10)
Change in current assets and current liabilities
Accounts receivable		13	(6)
Accounts payable		(59)	(26)
Unbilled revenues		17	3
Prepayments		(52)	3
Regulatory assets and liabilities		(12)	(40)
Taxes payable		(4)	(16)
Other		(6)	(6)
Other operating activities
Defined benefit plans - funding		(24)	0
Other assets		(4)	11
Other liabilities		1	(8)
Net cash provided by operating activities		279	328
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(550)	(424)
Expenditures for intangible assets		(5)	(2)
Net increase in notes receivable from affiliate		(270)	0
Other investing activities		1	(1)
Net cash used in investing activities		(824)	(427)
Cash Flows from Financing Activities
Issuance of long-term debt		470	224
Retirement of long-term debt		0	(224)
Contributions from parent		575	200
Payment of common stock dividends to parent		(154)	(117)
Net increase (decrease) in short-term debt		(295)	6
Other financing activities		(5)	(2)
Net cash provided by (used in) financing activities		591	87
Net Increase (Decrease) in Cash and Cash Equivalents		46	(12)
Cash and Cash Equivalents at Beginning of Period		13	47
Cash and Cash Equivalents at End of Period		59	35
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		157	130
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net Income		190	204
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		210	199
Amortization		14	15
Defined benefit plans - expense (income)		12	13
Deferred income taxes and investment tax credits		91	121
Other		0	(1)
Change in current assets and current liabilities
Accounts receivable		13	9
Accounts payable		(28)	28
Unbilled revenues		23	(14)
Fuel, materials and supplies		41	20
Taxes payable		3	(13)
Other		(21)	(23)
Other operating activities
Defined benefit plans - funding		(29)	(45)
Expenditures for asset retirement obligations		(12)	(8)
Other assets		(2)	1
Other liabilities		6	0
Net cash provided by operating activities		511	506
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(355)	(439)
Net cash used in investing activities		(355)	(439)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate		(4)	123
Issuance of long-term debt		60	0
Retirement of long-term debt		(60)	0
Debt issuance and credit facility costs		(1)	(1)
Net increase (decrease) in short-term debt		73	(126)
Distributions to member		(218)	(114)
Contributions from member		0	37
Net cash provided by (used in) financing activities		(150)	(81)
Net Increase (Decrease) in Cash and Cash Equivalents		6	(14)
Cash and Cash Equivalents at Beginning of Period		13	30
Cash and Cash Equivalents at End of Period		19	16
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		83	105
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net Income	[1]	96	96
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		89	83
Amortization		7	6
Defined benefit plans - expense (income)		3	4
Deferred income taxes and investment tax credits		57	62
Change in current assets and current liabilities
Accounts receivable		9	2
Accounts receivable from affiliates		11	(7)
Accounts payable		(17)	20
Accounts payable to affiliates		(3)	8
Unbilled revenues		14	(1)
Fuel, materials and supplies		33	29
Taxes payable		(23)	0
Other		(3)	(6)
Other operating activities
Defined benefit plans - funding		(3)	(16)
Expenditures for asset retirement obligations		(7)	(6)
Other assets		0	(4)
Other liabilities		1	3
Net cash provided by operating activities		264	273
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(177)	(237)
Net cash used in investing activities		(177)	(237)
Cash Flows from Financing Activities
Issuance of long-term debt		60	0
Retirement of long-term debt		(60)	0
Contributions from parent		0	47
Debt issuance and credit facility costs		(1)	(1)
Payment of common stock dividends to parent		(122)	(61)
Net increase (decrease) in short-term debt		38	(32)
Net cash provided by (used in) financing activities		(85)	(47)
Net Increase (Decrease) in Cash and Cash Equivalents		2	(11)
Cash and Cash Equivalents at Beginning of Period		5	19
Cash and Cash Equivalents at End of Period		7	8
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		40	69
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net Income	[2]	119	129
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		121	116
Amortization		6	7
Defined benefit plans - expense (income)		2	3
Deferred income taxes and investment tax credits		70	77
Other		0	(1)
Change in current assets and current liabilities
Accounts receivable		5	11
Accounts receivable from affiliates		0	1
Accounts payable		(1)	11
Accounts payable to affiliates		(15)	12
Unbilled revenues		9	(13)
Fuel, materials and supplies		8	(9)
Taxes payable		(29)	(3)
Other		(13)	(11)
Other operating activities
Defined benefit plans - funding		(21)	(13)
Expenditures for asset retirement obligations		(5)	(2)
Other assets		(3)	(3)
Other liabilities		4	(1)
Net cash provided by operating activities		257	311
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(177)	(201)
Net cash used in investing activities		(177)	(201)
Cash Flows from Financing Activities
Contributions from parent		0	20
Debt issuance and credit facility costs		0	(1)
Payment of common stock dividends to parent		(110)	(113)
Net increase (decrease) in short-term debt		35	(19)
Net cash provided by (used in) financing activities		(75)	(113)
Net Increase (Decrease) in Cash and Cash Equivalents		5	(3)
Cash and Cash Equivalents at Beginning of Period		7	11
Cash and Cash Equivalents at End of Period		12	8
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		$ 43	$ 36
[1]	Net income equals comprehensive income.
[2]	Net income approximates comprehensive income.

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Jun. 30, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents		$ 467	$ 341
Accounts receivable (less reserve:)
Customer		628	666
Other		85	46
Unbilled revenues		416	480
Fuel, materials and supplies		316	356
Prepayments		131	63
Price risk management assets		69	63
Regulatory assets		37	39
Other current assets		54	52
Total Current Assets		2,166	2,067
Property, Plant and Equipment
Regulated utility plant		36,173	34,674
Less: accumulated depreciation - regulated utility plant		6,446	6,013
Regulated utility plant, net		29,727	28,661
Non-regulated property, plant and equipment		424	413
Less: accumulated depreciation - non-regulated property, plant and equipment		147	134
Non-regulated property, plant and equipment, net		277	279
Construction work in progress		1,229	1,134
Property, Plant and Equipment, net		31,233	30,074
Other Noncurrent Assets
Regulatory assets		1,906	1,918
Goodwill		3,139	3,060
Other intangibles		656	700
Pension benefit asset		467	9
Price risk management assets		245	336
Other noncurrent assets		152	151
Total Other Noncurrent Assets		6,565	6,174
Total Assets		39,964	38,315
Current Liabilities
Short-term debt		1,497	923
Long-term debt due within one year		671	518
Accounts payable		752	820
Taxes		77	101
Interest		196	270
Dividends		271	259
Customer deposits		289	276
Regulatory liabilities		71	101
Other current liabilities		526	569
Total Current Liabilities		4,350	3,837
Long-term Debt
Long-term Debt		18,397	17,808
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		4,130	3,889
Investment tax credits		131	132
Accrued pension obligations		787	1,001
Asset retirement obligations		343	428
Regulatory liabilities		902	899
Other deferred credits and noncurrent liabilities		434	422
Total Deferred Credits and Other Noncurrent Liabilities		6,727	6,771
Commitments and Contingent Liabilities
Equity
Common stock	[1]	7	7
Additional paid-in capital		10,023	9,841
Earnings reinvested		3,983	3,829
Accumulated other comprehensive loss		(3,523)	(3,778)
Total Equity		10,490	9,899
Total Liabilities and Equity		39,964	38,315
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents		59	13
Accounts receivable (less reserve:)
Customer		267	272
Other		12	21
Accounts receivable from affiliates		1	0
Notes receivable from affiliate		270	0
Unbilled revenues		97	114
Fuel, materials and supplies		29	32
Prepayments		61	9
Regulatory assets		14	19
Other current assets		6	8
Total Current Assets		816	488
Property, Plant and Equipment
Regulated utility plant		10,235	9,654
Less: accumulated depreciation - regulated utility plant		2,814	2,714
Regulated utility plant, net		7,421	6,940
Construction work in progress		593	641
Property, Plant and Equipment, net		8,014	7,581
Other Noncurrent Assets
Regulatory assets		1,076	1,094
Other intangibles		254	251
Other noncurrent assets		15	12
Total Other Noncurrent Assets		1,345	1,357
Total Assets		10,175	9,426
Current Liabilities
Short-term debt		0	295
Long-term debt due within one year		224	224
Accounts payable		353	367
Accounts payable to affiliates		29	42
Taxes		8	12
Interest		37	34
Regulatory liabilities		57	83
Other current liabilities		88	101
Total Current Liabilities		796	1,158
Long-term Debt
Long-term Debt		3,074	2,607
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,990	1,899
Accrued pension obligations		257	281
Regulatory liabilities		0	0
Other deferred credits and noncurrent liabilities		90	90
Total Deferred Credits and Other Noncurrent Liabilities		2,337	2,270
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		2,729	2,154
Earnings reinvested		875	873
Total Equity		3,968	3,391
Total Liabilities and Equity		10,175	9,426
LG And E And KU Energy LLC [Member]
Assets
Cash and cash equivalents		19	13
Accounts receivable (less reserve:)
Customer		221	235
Other		40	17
Unbilled revenues		147	170
Fuel, materials and supplies		257	297
Prepayments		32	24
Regulatory assets		23	20
Other current assets		9	4
Total Current Assets		748	780
Property, Plant and Equipment
Regulated utility plant		12,852	12,746
Less: accumulated depreciation - regulated utility plant		1,630	1,465
Regulated utility plant, net		11,222	11,281
Construction work in progress		411	317
Property, Plant and Equipment, net		11,633	11,598
Other Noncurrent Assets
Regulatory assets		830	824
Goodwill		996	996
Other intangibles		90	95
Other noncurrent assets		80	78
Total Other Noncurrent Assets		1,996	1,993
Total Assets		14,377	14,371
Current Liabilities
Short-term debt		258	185
Long-term debt due within one year		98	194
Notes payable with affiliate		159	163
Accounts payable		225	251
Accounts payable to affiliates		6	6
Taxes		42	39
Price risk management liabilities		5	4
Interest		31	32
Customer deposits		57	56
Regulatory liabilities		14	18
Asset retirement obligations		73	60
Other current liabilities		115	119
Total Current Liabilities		1,083	1,127
Long-term Debt
Long-term debt		4,569	4,471
Long-term debt to affiliate		400	400
Long-term Debt		4,969	4,871
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,823	1,735
Investment tax credits		131	132
Accrued pension obligations		344	350
Asset retirement obligations		292	373
Regulatory liabilities		902	899
Price risk management liabilities		25	27
Other deferred credits and noncurrent liabilities		176	190
Total Deferred Credits and Other Noncurrent Liabilities		3,693	3,706
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(77)	(70)
Member's Equity		4,632	4,667
Total Liabilities and Equity		14,377	14,371
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents		7	5
Accounts receivable (less reserve:)
Customer		101	109
Other		11	11
Accounts receivable from affiliates		17	28
Unbilled revenues		61	75
Fuel, materials and supplies		110	143
Prepayments		15	12
Regulatory assets		11	9
Other current assets		3	1
Total Current Assets		336	393
Property, Plant and Equipment
Regulated utility plant		5,440	5,357
Less: accumulated depreciation - regulated utility plant		566	498
Regulated utility plant, net		4,874	4,859
Construction work in progress		174	133
Property, Plant and Equipment, net		5,048	4,992
Other Noncurrent Assets
Regulatory assets		449	450
Goodwill		389	389
Other intangibles		55	59
Other noncurrent assets		17	17
Total Other Noncurrent Assets		910	915
Total Assets		6,294	6,300
Current Liabilities
Short-term debt		207	169
Long-term debt due within one year		98	194
Accounts payable		116	148
Accounts payable to affiliates		23	26
Taxes		17	40
Price risk management liabilities		5	4
Interest		10	11
Customer deposits		27	27
Regulatory liabilities		4	5
Asset retirement obligations		29	41
Other current liabilities		40	36
Total Current Liabilities		576	701
Long-term Debt
Long-term Debt		1,521	1,423
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,033	974
Investment tax credits		36	36
Accrued pension obligations		49	53
Asset retirement obligations		103	104
Regulatory liabilities		418	419
Price risk management liabilities		25	27
Other deferred credits and noncurrent liabilities		83	87
Total Deferred Credits and Other Noncurrent Liabilities		1,747	1,700
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,682	1,682
Earnings reinvested		344	370
Total Equity		2,450	2,476
Total Liabilities and Equity		6,294	6,300
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents		12	7
Accounts receivable (less reserve:)
Customer		120	126
Other		27	5
Unbilled revenues		86	95
Fuel, materials and supplies		147	154
Prepayments		15	12
Regulatory assets		12	11
Other current assets		6	3
Total Current Assets		425	413
Property, Plant and Equipment
Regulated utility plant		7,404	7,382
Less: accumulated depreciation - regulated utility plant		1,062	965
Regulated utility plant, net		6,342	6,417
Construction work in progress		236	181
Property, Plant and Equipment, net		6,578	6,598
Other Noncurrent Assets
Regulatory assets		381	374
Goodwill		607	607
Other intangibles		35	36
Other noncurrent assets		60	57
Total Other Noncurrent Assets		1,083	1,074
Total Assets		8,086	8,085
Current Liabilities
Short-term debt		51	16
Accounts payable		94	78
Accounts payable to affiliates		43	56
Taxes		16	45
Interest		16	16
Customer deposits		30	29
Regulatory liabilities		10	13
Asset retirement obligations		44	19
Other current liabilities		32	36
Total Current Liabilities		336	308
Long-term Debt
Long-term Debt		2,327	2,327
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,242	1,170
Investment tax credits		95	96
Accrued pension obligations		38	62
Asset retirement obligations		189	269
Regulatory liabilities		484	480
Other deferred credits and noncurrent liabilities		42	50
Total Deferred Credits and Other Noncurrent Liabilities		2,090	2,127
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,616	2,616
Earnings reinvested		409	400
Accumulated other comprehensive loss		0	(1)
Total Equity		3,333	3,323
Total Liabilities and Equity		$ 8,086	$ 8,085
[1]	1,560,000 shares authorized; 685,473 and 679,731 shares issued and outstanding at June 30, 2017 and December 31, 2016.
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at June 30, 2017 and December 31, 2016.
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at June 30, 2017 and December 31, 2016.
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at June 30, 2017 and December 31, 2016.

CONDENSED CONSOLIDATED BALANCE7

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 53	$ 54
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)	685,473	679,731
Common stock shares outstanding (in shares)	685,473	679,731
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 26	$ 28
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	$ 25	$ 24
Louisville Gas And Electric Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 1	$ 2
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	$ 2
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 STATEME8

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, 2015			673,857	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2015		$ 9,919	$ 7		$ 9,687	$ 2,953	$ (2,728)	$ 3,119		$ 364		$ 1,934	$ 821		$ 2,330		$ 424		$ 1,611	$ 295	$ 3,287		$ 308		$ 2,596	$ 383	$ 0
Balance at beginning of period at Dec. 31, 2015														$ 4,517
Common stock shares issued	[1]		3,692
Common stock issued		109			109
Stock-based compensation		(30)			(30)
Net Income		964				964		173	[5]				173	204	96	[5]				96	129	[6]				129
Contributions from member														37
Capital contributions from parent								200				200			47				47		20				20
Dividends and dividend equivalents		(515)				(515)
Dividends declared on common stock								(116)					(116)		(61)					(61)	(113)					(113)
Distributions to member														(114)
Other comprehensive income (loss)		(129)					(129)							3							(1)						(1)
Adoption of stock-based compensation guidance cumulative effect adjustment		7				7
Balance at end of period - shares at Jun. 30, 2016			677,549	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at end of period at Jun. 30, 2016		$ 10,325	$ 7		9,766	3,409	(2,857)	$ 3,376		$ 364		2,134	878		$ 2,412		$ 424		1,658	330	$ 3,322		$ 308		2,616	399	(1)
Balance at end of period at Jun. 30, 2016														4,647
Balance at beginning of period - shares at Dec. 31, 2016		679,731	679,731	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		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]		5,742
Common stock issued		202			202
Stock-based compensation		(20)			(20)
Net Income		695				695		156	[5]				156	190	96	[5]				96	119	[6]				119
Capital contributions from parent								575				575
Dividends and dividend equivalents		(541)				(541)
Dividends declared on common stock								$ (154)					(154)		$ (122)					(122)	(110)					(110)
Distributions to member														(218)
Other comprehensive income (loss)		$ 255					255							(7)							$ 1						1
Balance at end of period - shares at Jun. 30, 2017		685,473	685,473	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Jun. 30, 2017		$ 10,490	$ 7		$ 10,023	$ 3,983	$ (3,523)	$ 3,968		$ 364		$ 2,729	$ 875		$ 2,450		$ 424		$ 1,682	$ 344	$ 3,333		$ 308		$ 2,616	$ 409	$ 0
Balance at end of period at Jun. 30, 2017														$ 4,632
[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 STATEME9

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical)	6 Months Ended
	Jun. 30, 2017Integer
Vote per share of PPL's common stock	1

Interim Financial Statements

Interim Financial Statements	6 Months Ended
	Jun. 30, 2017
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, 2016 is derived from that Registrant's 2016 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 2016 Form 10-K. The results of operations for the three and six months ended June 30, 2017 are not necessarily indicative of the results to be expected for the full year ending December 31, 2017 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	6 Months Ended
	Jun. 30, 2017
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 indicated Registrant's 2016 Form 10-K and should be read in conjunction with those disclosures. Accounts Receivable (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 six months ended June 30, 2017 , PPL Electric purchased $ 288 million and $644 million of accounts receivable from alternative energy suppliers. During the three and six months ended June 30, 2016, PPL Electric purchased $ 297 million and $679 million of accounts receivable from alternative electricity suppliers.

Segment and Related Information

Segment and Related Information	6 Months Ended
	Jun. 30, 2017
Segment Reporting [Abstract]
Segment and Related Information	3. Segment and Related Information (PPL) See Note 2 in PPL's 2016 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 June 30 are as follows: Three Months Six Months 2017 2016 2017 2016 Income Statement Data Revenues from external customers U.K. Regulated $ 502 $ 563 $ 1,070 $ 1,158 Kentucky Regulated 723 721 1,532 1,547 Pennsylvania Regulated 500 495 1,073 1,080 Corporate and Other — 6 1 11 Total $ 1,725 $ 1,785 $ 3,676 $ 3,796 Net Income U.K. Regulated (a) $ 148 $ 345 $ 434 $ 634 Kentucky Regulated 79 76 174 188 Pennsylvania Regulated 77 78 156 172 Corporate and Other (12 ) (16 ) (69 ) (30 ) Total $ 292 $ 483 $ 695 $ 964 (a) Includes unrealized gains and losses from hedging foreign-currency related economic activity. See Note 13 for additional information. Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: June 30, December 31, Balance Sheet Data Assets U.K. Regulated (a) $ 15,798 $ 14,537 Kentucky Regulated 14,043 14,037 Pennsylvania Regulated 10,175 9,426 Corporate and Other (b) (52 ) 315 Total $ 39,964 $ 38,315 (a) Includes $11.5 billion and $10.8 billion of net PP&E as of June 30, 2017 and December 31, 2016 . 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 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.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2017
Earnings Per Share [Abstract]
Earnings Per Share	4. 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. Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended June 30 used in the EPS calculation are: Three Months Six Months 2017 2016 2017 2016 Income (Numerator) Net income $ 292 $ 483 $ 695 $ 964 Less amounts allocated to participating securities — 1 1 3 Net income available to PPL common shareowners - Basic and Diluted $ 292 $ 482 $ 694 $ 961 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 683,841 677,145 682,370 676,293 Add incremental non-participating securities: Share-based payment awards 2,510 3,584 2,355 3,480 Weighted-average shares - Diluted EPS 686,351 680,729 684,725 679,773 Basic EPS Net Income available to PPL common shareowners $ 0.43 $ 0.71 $ 1.02 $ 1.42 Diluted EPS Net Income available to PPL common shareowners $ 0.43 $ 0.71 $ 1.01 $ 1.41 For the periods ended June 30 , PPL issued common stock related to stock-based compensation plans and the DRIP as follows (in thousands): Three Months Six Months 2017 2016 2017 2016 Stock-based compensation plans (a) 564 795 1,451 2,920 DRIP 369 370 814 772 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors. See Note 7 for additional information on common stock issued under the ATM Program. For the periods ended June 30 , the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months Six Months 2017 2016 2017 2016 Stock options 696 696 696 696 Performance units — 78 — 39

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2017
Income Tax Disclosure [Abstract]
Income Taxes	5. Income Taxes Reconciliations of income taxes for the periods ended June 30 are as follows. (PPL) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 129 $ 236 $ 315 $ 467 Increase (decrease) due to: State income taxes, net of federal income tax benefit 10 9 23 22 Valuation allowance adjustments — 3 5 9 Impact of lower U.K. income tax rates (40 ) (45 ) (88 ) (99 ) U.S. income tax on foreign earnings - net of foreign tax credit (a) (7 ) — (16 ) (2 ) Impact of the U.K. Finance Acts (6 ) (2 ) (9 ) (2 ) Depreciation not normalized (2 ) (3 ) (5 ) (4 ) Interest benefit on U.K. financing entities (4 ) (4 ) (8 ) (9 ) Stock-based compensation (4 ) (3 ) (7 ) (11 ) Other — 1 (5 ) — Total increase (decrease) (53 ) (44 ) (110 ) (96 ) Total income taxes $ 76 $ 192 $ 205 $ 371 (a) Lower income taxes primarily due to the tax benefit of accelerated pension contributions made in the first quarter of 2017. The related tax benefit is recognized over the annual period as a result of utilizing an estimated annual effective tax rate. (PPL Electric) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 44 $ 44 $ 88 $ 97 Increase (decrease) due to: State income taxes, net of federal income tax benefit 9 8 17 18 Depreciation not normalized (2 ) (2 ) (4 ) (3 ) Stock-based compensation (3 ) (2 ) (5 ) (7 ) Other (1 ) — (1 ) (1 ) Total increase (decrease) 3 4 7 7 Total income taxes $ 47 $ 48 $ 95 $ 104 (LKE) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 49 $ 47 $ 107 $ 114 Increase (decrease) due to: State income taxes, net of federal income tax benefit 5 5 11 12 Other (1 ) (1 ) (2 ) (3 ) Total increase (decrease) 4 4 9 9 Total income taxes $ 53 $ 51 $ 116 $ 123 (LG&E) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 24 $ 22 $ 55 $ 54 Increase (decrease) due to: State income taxes, net of federal income tax benefit 3 2 6 6 Other — — (1 ) (1 ) Total increase (decrease) 3 2 5 5 Total income taxes $ 27 $ 24 $ 60 $ 59 (KU) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 32 $ 31 $ 67 $ 73 Increase (decrease) due to: State income taxes, net of federal income tax benefit 3 3 7 7 Other (1 ) — (1 ) — Total increase (decrease) 2 3 6 7 Total income taxes $ 34 $ 34 $ 73 $ 80

Utility Rate Regulation

Utility Rate Regulation	6 Months Ended
	Jun. 30, 2017
Regulated Operations [Abstract]
Utility Rate Regulation	6. 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 June 30, December 31, June 30, December 31, Current Regulatory Assets: Environmental cost recovery $ 6 $ 6 $ — $ — Generation formula rate 10 11 — — Transmission service charge — 7 — 7 Gas supply clause 7 3 — — Smart meter rider 10 6 10 6 Storm costs 3 5 3 5 Other 1 1 1 1 Total current regulatory assets (a) $ 37 $ 39 $ 14 $ 19 Noncurrent Regulatory Assets: Defined benefit plans $ 920 $ 947 $ 537 $ 549 Taxes recoverable through future rates 345 340 345 340 Storm costs 40 58 — 10 Unamortized loss on debt 57 61 32 36 Interest rate swaps 124 129 — — Accumulated cost of removal of utility plant 162 159 162 159 AROs 245 211 — — Other 13 13 — — Total noncurrent regulatory assets $ 1,906 $ 1,918 $ 1,076 $ 1,094 PPL PPL Electric June 30, December 31, June 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 19 $ 23 $ 19 $ 23 Transmission service charge 6 — 6 — Universal service rider 14 14 14 14 Transmission formula rate 3 15 3 15 Fuel adjustment clause 13 11 — — Act 129 compliance rider 11 17 11 17 Storm damage expense 4 13 4 13 Other 1 8 — 1 Total current regulatory liabilities $ 71 $ 101 $ 57 $ 83 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 703 $ 700 $ — $ — Power purchase agreement - OVEC (b) 72 75 — — Net deferred tax assets 21 23 — — Defined benefit plans 27 23 — — Interest rate swaps 76 78 — — Other 3 — — — Total noncurrent regulatory liabilities $ 902 $ 899 $ — $ — LKE LG&E KU June 30, December 31, June 30, December 31, June 30, December 31, Current Regulatory Assets: Environmental cost recovery $ 6 $ 6 $ 4 $ 6 $ 2 $ — Generation formula rate 10 11 — — 10 11 Gas supply clause 7 3 7 3 — — Total current regulatory assets $ 23 $ 20 $ 11 $ 9 $ 12 $ 11 Noncurrent Regulatory Assets: Defined benefit plans $ 383 $ 398 $ 238 $ 246 $ 145 $ 152 Storm costs 40 48 22 26 18 22 Unamortized loss on debt 25 25 16 16 9 9 Interest rate swaps 124 129 85 88 39 41 AROs 245 211 84 70 161 141 Plant retirement costs 3 4 — — 3 4 Other 10 9 4 4 6 5 Total noncurrent regulatory assets $ 830 $ 824 $ 449 $ 450 $ 381 $ 374 LKE LG&E KU June 30, December 31, June 30, December 31, June 30, December 31, Current Regulatory Liabilities: Demand side management $ — $ 3 $ — $ 2 $ — $ 1 Fuel adjustment clause 13 11 4 2 9 9 Other 1 4 — 1 1 3 Total current regulatory liabilities $ 14 $ 18 $ 4 $ 5 $ 10 $ 13 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 703 $ 700 $ 308 $ 305 $ 395 $ 395 Power purchase agreement - OVEC (b) 72 75 50 52 22 23 Net deferred tax assets 21 23 21 23 — — Defined benefit plans 27 23 — — 27 23 Interest rate swaps 76 78 38 39 38 39 Other 3 — 1 — 2 — Total noncurrent regulatory liabilities $ 902 $ 899 $ 418 $ 419 $ 484 $ 480 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b) This liability was recorded as an offset to an intangible asset that was recorded at fair value upon the acquisition of LKE by PPL. Regulatory Matters Kentucky Activities (PPL, LKE, LG&E and KU) Rate Case Proceedings In November 2016, LG&E and KU filed requests with the KPSC for increases in annual base electricity and gas rates. LG&E's and KU's applications included requests for CPCNs for implementing an Advanced Metering System program and a Distribution Automation program. On April 19, 2017 and May 1, 2017, LG&E and KU, along with all intervening parties to the proceeding, filed with the KPSC, stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things, the proposed stipulations provided for increases in annual revenue requirements associated with KU base electricity rates of $ 55 million , LG&E base electricity rates of $ 59 million and LG&E base gas rates of $ 8 million , reflecting a return on equity of 9.75% , the withdrawal of LG&E's and KU's request for a CPCN for the Advanced Metering System and other changes to the revenue requirements, which dealt primarily with the timing of cost recovery, including depreciation rates. On June 22, 2017, the KPSC issued orders approving, with certain modifications, the proposed stipulations filed in April and May 2017. On June 29, 2017, the KPSC issued further orders correcting certain revenue requirement and rate calculations and making other technical corrections to the June 22, 2017 orders. The combined KPSC orders modified the stipulations to provide for increases in annual revenue requirements associated with KU base electricity rates of $ 52 million , LG&E base electricity rates of $ 57 million and LG&E base gas rates of $ 7 million , and incorporate an authorized return on equity of 9.7% . Consistent with the stipulations, the orders approved LG&E's and KU's request for implementing a Distribution Automation program and their withdrawal of a request for a CPCN for the Advanced Metering System program. The orders also approved new depreciation rates for LG&E and KU that will result in higher depreciation of approximately $15 million ( $4 million for LG&E and $11 million for KU) in 2017, exclusive of net additions to PP&E. The orders result in a base electricity rate increase of 3.2% at KU and base electricity and gas rate increases of 5.2% and 2.1% at LG&E. The new base rates and all elements of the orders became effective July 1, 2017. On June 23, 2017, the KPSC also issued orders establishing an authorized return on equity of 9.7% for all of LG&E's and KU's existing approved ECR plans and projects, replacing the prior authorized return on equity levels of 9.8% for CCR projects and 10% for all other ECR approved projects, effective with bills issued in August 2017. The impact of the new authorized return for ECR projects is not expected to be significant in 2017. 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 customers, the franchise fee will revert to zero . In August 2016, LG&E filed an application in a KPSC proceeding to review and rule upon the recoverability of the franchise fee. In August 2016, Louisville/Jefferson County submitted a motion to dismiss the proceeding filed by LG&E and, in November 2016, filed an amended complaint against LG&E relating to these issues. LG&E submitted KPSC filings to respond to, request dismissal of and consolidate certain claims or aspects of the proceedings. In January 2017, the KPSC issued an order denying Louisville/Jefferson County's motion to dismiss, consolidating the matter with LG&E's filed application and establishing a procedural schedule for the case. Louisville/Jefferson County and LG&E continue to file certain procedural motions, testimony and discovery with the KPSC. Until the KPSC issues a final order in this proceeding, LG&E cannot predict the ultimate outcome of this matter but does not anticipate that it will have a material effect on its financial condition or results of operation. LG&E continues to provide gas service to customers in this franchise area at existing rates, but without collecting or remitting a franchise fee.

Financing Activities

Financing Activities	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Financing Activities	7. Financing Activities Credit Arrangements and Short-term Debt (All Registrants) The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LKE, LG&E and KU also apply to PPL and the credit facilities and commercial paper programs of LG&E and KU also apply to LKE. The amounts borrowed below are recorded as "Short-term debt" on the Balance Sheets. The following credit facilities were in place at: June 30, 2017 December 31, 2016 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. 2022 £ 210 £ 155 £ — £ 56 £ 160 £ — Term Loan Facility (b) Dec. 2017 230 230 — — — — WPD (South West) Syndicated Credit Facility (c) July 2021 245 80 — 165 110 — WPD (East Midlands) Syndicated Credit Facility (d) July 2021 300 116 — 184 9 — WPD (West Midlands) Syndicated Credit Facility July 2021 300 — — 300 — — Uncommitted Credit Facilities (e) 90 50 4 36 60 4 Total U.K. Credit Facilities (f) £ 1,375 £ 631 £ 4 £ 741 £ 339 £ 4 June 30, 2017 December 31, 2016 Expiration Date Capacity Borrowed Letters of Credit and Commercial Paper Issued Unused Capacity Borrowed Letters of Credit and Commercial Paper Issued U.S. PPL Capital Funding Syndicated Credit Facility Jan. 2022 $ 950 $ — $ 424 $ 526 $ — $ 20 Syndicated Credit Facility Nov. 2018 300 — — 300 — — Bilateral Credit Facility Mar. 2018 150 — 17 133 — 17 Total PPL Capital Funding Credit Facilities $ 1,400 $ — $ 441 $ 959 $ — $ 37 PPL Electric Syndicated Credit Facility Jan. 2022 $ 650 $ — $ 1 $ 649 $ — $ 296 LKE Syndicated Credit Facility Oct. 2018 $ 75 $ — $ — $ 75 $ — $ — LG&E Syndicated Credit Facility Jan. 2022 $ 500 $ — $ 207 $ 293 $ — $ 169 KU Syndicated Credit Facility Jan. 2022 $ 400 $ — $ 51 $ 349 $ — $ 16 Letter of Credit Facility Oct. 2017 198 — 198 — — 198 Total KU Credit Facilities $ 598 $ — $ 249 $ 349 $ — $ 214 (a) The amounts borrowed at June 30, 2017 and December 31, 2016 were USD-denominated borrowings of $200 million for both periods, which bore interest at 1.87% and 1.43% . The unused capacity reflects the amount borrowed in GBP of £154 million as of the date borrowed. (b) The amount borrowed at June 30, 2017 was a GBP-denominated borrowing which equated to $297 million and bore interest at 1.50% . (c) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $103 million and $137 million and bore interest at 0.65% and 0.66% . (d) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $150 million and $11 million and bore interest at 0.65% and 0.66% . (e) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $65 million and $75 million and bore interest at 1.07% and 1.26% . (f) At June 30, 2017 , the unused capacity under the U.K. credit facilities was $956 million . (PPL, LKE and KU) In August 2017, the expiration date for the KU letter of credit facility was extended to October 2020 . (All Registrants) PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, 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: June 30, 2017 December 31, 2016 Weighted - Average Interest Rate Capacity Commercial Paper Issuances Unused Capacity Weighted - Average Interest Rate Commercial Paper Issuances PPL Capital Funding 1.46% $ 1,000 $ 424 $ 576 1.10% $ 20 PPL Electric 650 — 650 1.05% 295 LG&E 1.35% 350 207 143 0.94% 169 KU 1.40% 350 51 299 0.87% 16 Total $ 2,350 $ 682 $ 1,668 $ 500 (PPL Electric and LKE) See Note 10 for discussion of intercompany borrowings. Long-term Debt (PPL) In March 2017, WPD (South Wales) issued £50 million of 0.01% Index-linked Senior Notes due 2029 . WPD (South Wales) received proceeds of £53 million , which equated to $64 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. (PPL and PPL Electric) In May 2017, PPL Electric issued $475 million of 3.95% First Mortgage Bonds due 2047 . PPL Electric received proceeds of $466 million , net of a discount and underwriting fees, which were used to repay short-term debt incurred primarily for capital expenditures. (PPL, LKE and LG&E) In June 2017, the County of Trimble, Kentucky issued $60 million of Environmental Facilities Revenue Refunding Bonds, 2017 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were issued bearing interest at a rate of 3.75% through their maturity and are subject to an optional redemption on or after June 1, 2027 . The proceeds of the bonds were used to redeem $60 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued by the County of Trimble, Kentucky on behalf of LG&E. In June 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.25% through their mandatory purchase date of June 3, 2019 . In June 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $35 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series B (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.25% through their mandatory purchase date of June 3, 2019 . In April 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $128 million of Pollution Control Revenue Bonds, 2003 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.50% through their mandatory purchase date of April 1, 2019 . (PPL) ATM Program In February 2015, PPL entered into two separate equity distribution agreements, pursuant to which PPL may sell, from time to time, up to an aggregate of $500 million of its common stock. For the periods ended June 30 , PPL issued the following: Three Months Six Months 2017 2016 2017 2016 Number of shares (in thousands) 2,113 — 3,477 — Average share price $ 39.15 $ — $ 38.17 $ — Net Proceeds $ 82 $ — $ 132 $ — Distributions In May 2017 , PPL declared a quarterly common stock dividend, payable July 3, 2017 , of 39.5 cents per share (equivalent to $1.58 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	6 Months Ended
	Jun. 30, 2017
Compensation and Retirement Disclosure [Abstract]
Defined Benefits	8. 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 June 30 : Pension Benefits Three Months Six Months U.S. U.K. U.S. U.K. 2017 2016 2017 2016 2017 2016 2017 2016 PPL Service cost $ 15 $ 16 $ 18 $ 18 $ 32 $ 33 $ 37 $ 36 Interest cost 42 44 44 62 84 87 87 124 Expected return on plan assets (58 ) (58 ) (127 ) (132 ) (115 ) (114 ) (252 ) (265 ) Amortization of: Prior service cost 3 3 — — 5 4 — — Actuarial loss 14 10 36 36 34 25 71 73 Net periodic defined benefit costs (credits) before special termination benefits 16 15 (29 ) (16 ) 40 35 (57 ) (32 ) Special termination benefits (a) (1 ) — — — 1 — — — Net periodic defined benefit costs (credits) $ 15 $ 15 $ (29 ) $ (16 ) $ 41 $ 35 $ (57 ) $ (32 ) (a) 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 Six Months 2017 2016 2017 2016 LKE Service cost $ 5 $ 6 $ 12 $ 12 Interest cost 18 18 34 35 Expected return on plan assets (24 ) (24 ) (46 ) (45 ) Amortization of: Prior service cost 2 3 4 4 Actuarial loss 4 5 15 10 Net periodic defined benefit costs $ 5 $ 8 $ 19 $ 16 Pension Benefits Three Months Six Months 2017 2016 2017 2016 LG&E Service cost $ 1 $ 1 $ 1 $ 1 Interest cost 3 4 $ 6 $ 7 Expected return on plan assets (6 ) (5 ) (11 ) (10 ) Amortization of: Prior service cost 1 1 2 2 Actuarial loss 1 1 4 3 Net periodic defined benefit costs $ — $ 2 $ 2 $ 3 Other Postretirement Benefits Three Months Six Months 2017 2016 2017 2016 PPL Service cost $ 2 $ 2 $ 4 $ 4 Interest cost 6 7 12 13 Expected return on plan assets (5 ) (6 ) (11 ) (11 ) Amortization of prior service cost (1 ) — (1 ) — Net periodic defined benefit costs $ 2 $ 3 $ 4 $ 6 LKE Service cost $ 1 $ 1 $ 2 $ 2 Interest cost 2 3 4 5 Expected return on plan assets (2 ) (1 ) (3 ) (3 ) Amortization of prior service cost — — — 1 Net periodic defined benefit costs $ 1 $ 3 $ 3 $ 5 (PPL Electric, LG&E and KU) In addition to the specific plans 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. These allocations are based on participation in those plans, which management believes are reasonable. For the periods ended June 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 Six Months 2017 2016 2017 2016 PPL Electric $ 5 $ 5 $ 13 $ 11 LG&E 2 3 5 5 KU 1 3 5 6 Expected Cash Flows - U.K. Pension Plans (PPL) For the six months ended June 30, 2017, WPD contributed $485 million to its U.K. pension plans. These accelerated contributions fund all 2017 required contributions and a portion of 2018 required contributions. WPD does not expect to make additional contributions in 2017.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	9. 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. WKE Indemnification (PPL and LKE) See footnote (e) to the table in "Guarantees and Other Assurances" below for information on an LKE indemnity relating to its former WKE lease, including related legal proceedings. 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 alleging violations of the Clean Air Act and RCRA. In addition, these plaintiffs assert 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. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In response to a motion to dismiss filed by PPL and LG&E, in July 2014, the court dismissed the plaintiffs' RCRA claims and all but one Clean Air Act claim, but declined to dismiss the common law tort claims. In November 2016, plaintiffs filed an amended complaint removing the personal injury claims and removing certain previously named plaintiffs. In February 2017, the District Court issued an order dismissing PPL as a defendant and dismissing the final federal claim against LG&E under the Clean Air Act, and directed the parties to submit briefs regarding whether the court should continue to exercise supplemental jurisdiction regarding the remaining state law-only claims. On April 13, 2017, the District Court issued an order declining to exercise supplemental jurisdiction and dismissing the case in its entirety, subject to certain federal appeals or state court re-filing rights of the parties. On June 16, 2017, the plaintiffs filed a class action complaint in Jefferson Circuit Court, Kentucky, against LG&E regarding the 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. PPL, LKE and LG&E cannot predict the outcome of this matter. LG&E retired one coal-fired unit at the Cane Run plant in March 2015 and the remaining two coal-fired units at the plant in June 2015. 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 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 seek injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act violations, including ceasing the discharges in question, abating effects associated with prior discharges and eliminating the alleged imminent and substantial endangerment. These plaintiffs also seek assessment of civil penalties and an award of litigation costs and attorney fees. PPL, LKE and KU cannot predict the outcome of this matter or the potential impact on the operations of the E.W. Brown plant, including increased capital or operating costs, if any. (PPL, LKE, LG&E and KU) Trimble County Water Discharge Permit In May 2010, the Kentucky Waterways Alliance and other environmental groups filed a petition with the Kentucky Energy and Environment Cabinet (KEEC) challenging the Kentucky Pollutant Discharge Elimination System permit issued in April 2010, which covers water discharges from the Trimble County plant. In November 2010, the KEEC issued a final order upholding the permit, which was subsequently appealed by the environmental groups. In September 2013, the Franklin Circuit Court reversed the KEEC order upholding the permit and remanded the permit to the agency for further proceedings. LG&E and the KEEC appealed the order to the Kentucky Court of Appeals. In July 2015, the Court of Appeals upheld the lower court ruling. LG&E and the KEEC moved for discretionary review by the Kentucky Supreme Court. In February 2016, the Kentucky Supreme Court issued an order granting discretionary review and oral arguments were held in September 2016. On April 27, 2017, the Kentucky Supreme Court issued an order reversing the decision of the appellate court and upholding the permit issued to LG&E by the KEEC. PPL, LKE, LG&E and KU are unable to predict the outcome of this matter or the potential impact on the operations of the Trimble County plant, including increased capital or operating costs, if any, but do not expect such costs to be material. Trimble County Landfill Various state and federal permits and regulatory approvals are required in order to construct a landfill at the Trimble County plant to be used for disposal of CCRs. In October 2016, the Kentucky Division of Water issued a water quality certification and in February 2017, the Kentucky Division of Waste Management issued a “special waste” landfill permit. In March 2017, the Sierra Club and a resident adjacent to the plant filed administrative challenges to the landfill permit before the KEEC. In June 2017, the U.S. Army Corps of Engineers issued a dredge and fill permit, the final approval required for construction of the landfill. PPL, LKE, LG&E and KU believe that all permits and regulatory approvals issued for the project comply with applicable state and federal laws, but cannot predict the outcome of legal challenges or the potential impact, if any, on plant operations, or future capital or operating costs. However, PPL, LKE, LG&E and KU believe that additional costs, if any, resulting from such legal challenges would be subject to cost recovery. Regulatory Issues ( All Registrants) See Note 6 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 cannot estimate a range of reasonably possible losses, if any. 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) 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 plants. The Clean Air Act requires the EPA periodically to review and establish concentration levels in the ambient air for six criteria pollutants to protect public health and welfare. These concentration levels are known as NAAQS. The six criteria pollutants are carbon monoxide, lead, nitrogen dioxide, ozone, particulate matter and sulfur dioxide. Federal environmental regulations of these criteria pollutants require states to adopt implementation plans, known as state implementation plans, for certain pollutants, 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. National Ambient Air Quality Standards (NAAQS) Under the Clean Air Act, the EPA is required to reassess the NAAQS for certain air pollutants on a five-year schedule. In 2008, the EPA revised the NAAQS for ozone and proposed to further strengthen the standard in November 2014. The EPA released a new ozone standard on October 1, 2015. The states and the EPA will determine attainment with the new ozone standard through review of relevant ambient air monitoring data, with attainment or nonattainment designations scheduled no later than October 2018. States are also obligated to address interstate transport issues associated with new 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. States that are not in the ozone transport region, including Kentucky, worked together to evaluate the need for further nitrogen oxide reductions from fossil-fueled plants with SCRs. Based on regulatory developments to date, PPL, LKE, LG&E and KU do not anticipate requirements for nitrogen oxide reductions beyond those currently required under the Cross State Air Pollution Rule. In 2010, the EPA finalized revised NAAQS for sulfur dioxide and required states to identify areas that meet those standards and areas that are in "non-attainment". In July 2013, the EPA finalized non-attainment designations for parts of the country, including part of Jefferson County in Kentucky. Attainment must be achieved by 2018. Based on regulatory developments to date, PPL, LKE, LG&E and KU expect that certain previously required compliance measures, such as upgraded or new sulfur dioxide Scrubbers and additional sulfur dioxide limits at certain plants and the retirement of coal-fired generating units at LG&E's Cane Run plant and KU's Green River plant, are sufficient to achieve compliance with the new sulfur dioxide and ozone 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 Clean Power Plan described below, 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, in March 2017, the President issued an Executive Order (the March 2017 Executive Order) directing the EPA to review proposed and final rules relating to GHG reductions 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 included in WPD's current operating expenses. The EPA's Rules under Section 111 of the Clean Air Act, including the EPA's Clean Power Plan As further described below, the EPA finalized rules imposing GHG emission standards for both new and existing power plants. The EPA has also issued a proposed federal implementation plan that would apply to any states that fail to submit an acceptable state implementation plan under these rules. The future of these rules is uncertain. The EPA's authority to promulgate these regulations under Section 111 of the Clean Air Act has been challenged in the D.C. Circuit Court by several states and industry groups. In February 2016, the U.S. Supreme Court stayed the rule for existing plants (the Clean Power Plan) pending the D.C. Circuit Court's review and subsequent review by the U.S. Supreme Court if a writ of certiorari is filed and granted. In addition, the President's March 2017 Executive Order requires the EPA to review the rules for new plants and existing power plants and suspend, revise or rescind them as appropriate. The EPA's rule for new power plants imposes separate emission standards for coal and natural gas units based on the application of different technologies. The coal standard is based on the application of partial carbon capture and sequestration technology, but because this technology is not presently commercially viable, the rule effectively precludes the construction of new coal-fired plants. The standard for NGCC power plants is the same as what the EPA proposed in 2012 and is not continuously achievable. The preclusion of new coal-fired plants and the compliance difficulties posed for new natural gas-fired plants could have a significant industry-wide impact. The EPA's rule for existing power plants, referred to as the Clean Power Plan, was published in the Federal Register in October 2015. The Clean Power Plan contains state-specific rate-based and mass-based reduction goals and guidelines for the development, submission and implementation of state implementation plans to achieve the state goals. State-specific goals were calculated from 2012 data by applying the EPA's broad interpretation and definition of the BSER, resulting in the most stringent targets to be met in 2030, with interim targets to be met beginning in 2022. The EPA believes it has offered some flexibility to the states as to how their compliance plans can be crafted, including the option to use a rate-based approach (limit emissions per megawatt hour) or a mass-based approach (limit total tons of emissions per year), and the option to demonstrate compliance through emissions trading and multi-state collaborations. Under the rate-based approach, Kentucky would need to make a 41% reduction from its 2012 emissions rate and under a mass-based approach it would need to make a 36% reduction. These reductions are significantly greater than initially proposed and present significant challenges to the state. If the Clean Power Plan is ultimately upheld and Kentucky fails to develop an approvable implementation plan by the applicable deadline, the EPA may impose a federal implementation plan that could be more stringent than what the state plan might provide. Depending on the provisions of the Kentucky implementation plan, LG&E and KU may need to modify their current portfolio of generating assets during the next decade and/or participate in an allowance trading program. LG&E and KU are monitoring developments at the state and federal level. Various states, industry groups and individual companies including LKE have filed petitions for reconsideration with the EPA and petitions for review with the D.C. Circuit Court challenging the Clean Power Plan. In February 2016, the U.S. Supreme Court stayed the rule pending the D.C. Circuit Court's review. The EPA has commenced review of the Clean Power Plan and related actions, as directed by the President's March 2017 Executive Order. In April 2017, in response to a motion filed by the EPA, the D.C. Circuit temporarily held the litigation in abeyance in light of the EPA's ongoing review of the Clean Power Plan. PPL, LKE, LG&E and KU cannot predict the outcome of the pending litigation, any changes in regulations, interpretations, or litigation positions that may be implemented by the U.S. presidential administration or the potential impact, if any, on plant operations, or future capital or operating costs. PPL, LKE, LG&E and KU believe that the costs, which could be significant, would be subject to cost recovery. 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 EPA's regulations governing GHG emissions from existing sources, 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 may make it more difficult for Kentucky to achieve the GHG reduction levels that the EPA has established for Kentucky, if enacted. 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. 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) Coal Combustion Residuals (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. Recently enacted federal legislation has authorized the EPA to approve equally protective state programs that would operate in lieu of the CCR Rule. In January 2017, Kentucky issued a state rule, effective May 2017, aimed at reflecting the requirements of the federal rule. In May 2017, a resident adjacent to LG&E's and KU's Trimble County plant filed a lawsuit in state court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. PPL, LKE, LG&E and KU cannot predict the outcome of the litigation, but anticipate continued operation under the former program in the event that the new rule is struck down. LG&E and KU have received KPSC approval for a compliance plan providing for construction of additional landfill capacity at the E.W. Brown station, 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 federal CCR rule requirements, 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 requirements. See Note 6 in the Registrants' 2016 Form 10-K for additional information. In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs during 2015, 2016 and 2017. See Note 15 below and Note 19 in the Registrants' 2016 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. Effluent Limitations Guidelines (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 June 2017, the EPA published in the Federal Register a rule that would postpone applicable compliance dates until the agency completes reconsideration of the rule. 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 at this time, although certain preliminary estimates are included in current capital forecasts for applicable periods. 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 Seepages or groundwater infiltration have been detected at active and retired wastewater basins and landfills at various LG&E and KU plants. 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. A range of reasonably possible costs cannot currently be estimated. Depending on the circumstances in each case, certain costs, which may be subject to rate recovery, could be significant. (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, currently scheduled for November 2017, 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. Superfund and Other Remediation PPL Electric is potentially responsible for a share of the costs at several sites listed by the EPA under the federal Superfund program, including the Columbia Gas Plant site and the Brodhead site. Clean-up actions have been or are being undertaken at all of these sites, the costs of which have not been, and are not expected to be, significant to PPL Electric. PPL Electric, LG&E and KU are investigating, responding to agency inquiries, remediating, or have completed the remediation of, several sites that were not addressed under a regulatory program such as Superfund, but for which PPL Electric, LG&E and KU may be liable for remediation. These include a number of former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operated or currently owned by predecessors or affiliates of PPL Electric, LG&E and KU. To date, the costs of these sites have not been significant. There are additional sites, formerly owned or operated by PPL Electric, LG&E and KU predecessors or affiliates. PPL Electric, LG&E and KU lack sufficient information on such additional sites and are therefore unable to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters. At June 30, 2017 and December 31, 2016, PPL Electric had a recorded liability of $10 million representing its best estimate of the probable loss incurred to remediate the sites noted above. Depending on the outcome of investigations at sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred; however, such costs are not expected to be significant. The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result of the EPA's evaluation, individual states may establish stricter standards for water quality and soil cleanup. This could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. PPL, PPL Electric, LKE, LG&E and KU cannot estimate a range of reasonably possible losses, if any, related to these matters. From time to time, PPL's subsidiaries in the United States undertake testing, monitoring or remedial action in response to notices of violations, spills or other releases at various on-site and off-site locations, negotiate with the EPA and state and local agencies regarding actions necessary for compliance with applicable requirements, negotiate with property owners and other third parties alleging impacts from PPL's operations and

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2017
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	10. 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, as applicable, 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. 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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105 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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81% . (LKE) LKE maintains a $225 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2017 and December 31, 2016 , $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12% . LKE maintains a $400 million ten -year note with a PPL affiliate with an interest rate of 3.5% . At June 30, 2017 and December 31, 2016 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 8 for discussions regarding intercompany allocations associated with defined benefits.
LG And E And KU Energy LLC [Member]
Related Party Transactions [Line Items]
Related Party Transactions	10. 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, as applicable, 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. 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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105 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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81% . (LKE) LKE maintains a $225 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2017 and December 31, 2016 , $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12% . LKE maintains a $400 million ten -year note with a PPL affiliate with an interest rate of 3.5% . At June 30, 2017 and December 31, 2016 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 8 for discussions regarding intercompany allocations associated with defined benefits.
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	10. 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, as applicable, 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. 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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105 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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81% . (LKE) LKE maintains a $225 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2017 and December 31, 2016 , $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12% . LKE maintains a $400 million ten -year note with a PPL affiliate with an interest rate of 3.5% . At June 30, 2017 and December 31, 2016 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 8 for discussions regarding intercompany allocations associated with defined benefits.
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	10. 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, as applicable, 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. 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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105 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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81% . (LKE) LKE maintains a $225 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2017 and December 31, 2016 , $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12% . LKE maintains a $400 million ten -year note with a PPL affiliate with an interest rate of 3.5% . At June 30, 2017 and December 31, 2016 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 8 for discussions regarding intercompany allocations associated with defined benefits.

Other Income (Expense) - net

Other Income (Expense) - net	6 Months Ended
	Jun. 30, 2017
Other Nonoperating Income (Expense) [Abstract]
Other Income (Expense) - net	11. Other Income (Expense) - net (PPL) "Other Income (Expense) - net" for the three and six months ended June 30, 2017 and 2016 consisted primarily of gains (losses) on foreign currency contracts to economically hedge PPL's translation risk related to its GBP denominated earnings in the U.K. See Note 13 for additional information on these derivatives.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements	12. 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 six months ended June 30, 2017 and 2016 , there were no transfers between Level 1 and Level 2. See Note 1 in each Registrant's 2016 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: June 30, 2017 December 31, 2016 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 467 $ 467 $ — $ — $ 341 $ 341 $ — $ — Restricted cash and cash equivalents (a) 25 25 — — 26 26 — — Price risk management assets (b): Foreign currency contracts 156 — 156 — 211 — 211 — Cross-currency swaps 158 — 158 — 188 — 188 — Total price risk management assets 314 — 314 — 399 — 399 — Total assets $ 806 $ 492 $ 314 $ — $ 766 $ 367 $ 399 $ — Liabilities Price risk management liabilities (b): Interest rate swaps $ 31 $ — $ 31 $ — $ 31 $ — $ 31 $ — Foreign currency contracts 104 — 104 — 27 — 27 — Total price risk management liabilities $ 135 $ — $ 135 $ — $ 58 $ — $ 58 $ — PPL Electric Assets Cash and cash equivalents $ 59 $ 59 $ — $ — $ 13 $ 13 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 61 $ 61 $ — $ — $ 15 $ 15 $ — $ — LKE Assets Cash and cash equivalents $ 19 $ 19 $ — $ — $ 13 $ 13 $ — $ — Cash collateral posted to counterparties (c) 2 2 — — 3 3 — — Total assets $ 21 $ 21 $ — $ — $ 16 $ 16 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — Total price risk management liabilities $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — LG&E Assets Cash and cash equivalents $ 7 $ 7 $ — $ — $ 5 $ 5 $ — $ — Cash collateral posted to counterparties (c) 2 2 — — 3 3 — — Total assets $ 9 $ 9 $ — $ — $ 8 $ 8 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — Total price risk management liabilities $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — June 30, 2017 December 31, 2016 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 KU Assets Cash and cash equivalents $ 12 $ 12 $ — $ — $ 7 $ 7 $ — $ — Total assets $ 12 $ 12 $ — $ — $ 7 $ 7 $ — $ — (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. (c) Included in "Other noncurrent assets" on the Balance Sheets. Represents cash collateral posted to offset the exposure with counterparties related to certain interest rate swaps under master netting arrangements that are not offset. 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. The fair values were estimated using an income approach by discounting future cash flows at estimated current cost of funding rates, which incorporate the credit risk of the Registrants. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement. June 30, 2017 December 31, 2016 Carrying Amount (a) Fair Value Carrying Amount (a) Fair Value PPL $ 19,068 $ 22,791 $ 18,326 $ 21,355 PPL Electric 3,298 3,705 2,831 3,148 LKE 5,067 5,535 5,065 5,439 LG&E 1,619 1,749 1,617 1,710 KU 2,327 2,572 2,327 2,514 (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	6 Months Ended
	Jun. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	13. 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 the 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 mechanisms in place. Foreign currency risk • PPL is exposed to foreign currency exchange risk primarily associated with its investments in and earnings of U.K. affiliates. Commodity price risk PPL is exposed to commodity price risk through its domestic subsidiaries as described below. • PPL Electric is exposed to commodity price risk from its obligation as PLR; however, its PUC-approved cost recovery mechanism substantially eliminates its exposure to this risk. PPL Electric also mitigates its exposure to commodity price risk by entering into full-requirement supply agreements to serve its PLR customers. These supply agreements transfer the commodity price risk associated with the PLR obligation to the energy suppliers. • LG&E's and KU's rates include certain mechanisms for fuel and fuel-related expenses. 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 period, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 2016 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 mechanisms 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 LG&E, KU or PPL Electric defaults on its obligation, those entities 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, thus 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 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 $27 million obligation to return cash collateral under master netting arrangements at June 30, 2017 and a $19 million obligation to return cash collateral under master netting arrangements at December 31, 2016 . LKE and LG&E had no obligation to return cash collateral under master netting arrangements at June 30, 2017 and December 31, 2016 . PPL, LKE and LG&E posted $2 million of cash collateral under master netting arrangements at June 30, 2017 and $3 million of cash collateral under master netting arrangements at December 31, 2016 . 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. Various financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolio, adjust the duration of the debt portfolio 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 June 30, 2017 , PPL held an aggregate notional value in interest rate swap contracts of £145 million (approximately $187 million based on spot rates) that mature in 2027 to hedge the interest payments of anticipated WPD debt issuances. These swaps require a mandatory early redemption on or before November 30, 2017 . For the three and six months ended June 30, 2017 , PPL had no hedge ineffectiveness associated with interest rate derivatives. For the three and six months ended June 30, 2016, PPL had an insignificant amount of hedge ineffectiveness associated with interest rate derivatives. At June 30, 2017 , PPL held an aggregate notional value in cross-currency interest rate swap contracts of $802 million that range in maturity from 2017 through 2028 to hedge the interest payments and principal of WPD's U.S. dollar-denominated senior notes. For the three and six months ended June 30, 2017 and 2016 , PPL had no hedge ineffectiveness associated with cross-currency interest rate swap derivatives. Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring. For the three and six months ended June 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and six months ended June 30, 2016 , PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At June 30, 2017 , 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 June 30, 2017 , 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 such contracts outstanding at June 30, 2017 . At June 30, 2017 and December 31, 2016 , PPL had $21 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 June 30, 2017 , the total exposure hedged by PPL was approximately £2.8 billion (approximately $3.7 billion based on contracted rates). These contracts had termination dates ranging from July 2017 through December 2019 . 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 and KU's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at June 30, 2017 and December 31, 2016 . See Notes 1 and 17 in each Registrant's 2016 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. June 30, 2017 December 31, 2016 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) $ — $ 1 $ — $ 5 $ — $ — $ — $ 4 Cross-currency swaps (b) 28 — — — 32 — — — Foreign currency contracts — — 41 60 — — 31 21 Total current 28 1 41 65 32 — 31 25 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 25 — — — 27 Cross-currency swaps (b) 130 — — — 156 — — — Foreign currency contracts — — 115 44 — — 180 6 Total noncurrent 130 — 115 69 156 — 180 33 Total derivatives $ 158 $ 1 $ 156 $ 134 $ 188 $ — $ 211 $ 58 (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 June 30, 2017 . Three Months Six Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Six Months Cash Flow Hedges: Interest rate swaps $ (2 ) $ (2 ) Interest expense $ (2 ) $ — $ (4 ) $ (1 ) Cross-currency swaps (27 ) (35 ) Interest expense (1 ) — — — Other income (expense) - net (29 ) — (26 ) — Total $ (29 ) $ (37 ) $ (32 ) $ — $ (30 ) $ (1 ) Net Investment Hedges: Foreign currency contracts $ — $ — Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Six Months Foreign currency contracts Other income (expense) - net $ (113 ) $ (156 ) Interest rate swaps Interest expense (1 ) (3 ) Total $ (114 ) $ (159 ) Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 1 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 June 30, 2016 . Three Months Six Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Six Months Cash Flow Hedges: Interest rate swaps $ (3 ) $ (21 ) Interest expense $ (2 ) $ — $ (3 ) $ — Cross-currency swaps (104 ) 9 Interest expense (1 ) — — — Other income (expense) - net (103 ) — (6 ) — Total $ (107 ) $ (12 ) $ (106 ) $ — $ (9 ) $ — Net Investment Hedges: Foreign currency contracts $ 1 $ 4 Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Six Months Foreign currency contracts Other income (expense) - net $ 171 $ 231 Interest rate swaps Interest expense (2 ) (4 ) Total $ 169 $ 227 Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (3 ) $ (9 ) (LKE and LG&E) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. June 30, 2017 December 31, 2016 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 5 $ — $ 4 Total current — 5 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 25 — 27 Total noncurrent — 25 — 27 Total derivatives $ — $ 30 $ — $ 31 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 June 30, 2017 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Six Months Interest rate swaps Interest expense $ (1 ) $ (3 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 1 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 June 30, 2016 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Six Months Interest rate swaps Interest expense $ (2 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (3 ) $ (9 ) (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 June 30, 2017 Treasury Derivatives PPL $ 314 $ 93 $ 27 $ 194 $ 135 $ 93 $ 2 $ 40 LKE — — — — 30 — 2 28 LG&E — — — — 30 — 2 28 December 31, 2016 Treasury Derivatives PPL $ 399 $ 27 $ 19 $ 353 $ 58 $ 27 $ 3 $ 28 LKE — — — — 31 — 3 28 LG&E — — — — 31 — 3 28 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 June 30, 2017 , 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 $ 23 $ 12 $ 12 Aggregate fair value of collateral posted on these derivative instruments 2 2 2 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 21 10 10 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Goodwill

Goodwill	6 Months Ended
	Jun. 30, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets	14. Goodwill and Other Intangible Assets (PPL) The change in the carrying amount of goodwill for the six months ended June 30, 2017 was due to the effect of foreign currency exchange rates on the U.K. Regulated segment. The change in the carrying amount of other intangible assets for the six months ended June 30, 2017 was primarily due to a change in WPD’s approach in acquiring rights-of-way relating to WPD equipment impacting landowners' property. A shorter term agreement at a lower cost is now being offered which has also reduced the estimated liability for claims not yet settled.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2017
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233 PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final 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 approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. 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. LKE recorded decreases of $66 million ( $56 million at KU and $10 million at LG&E) to the existing AROs during the three and six months ended June 30, 2017 related to the closure of CCR impoundments. These revisions are the result of changes in closure plans related to expected costs and timing of closures. Further changes to AROs, capital plans or operating costs may be required as estimates of future cash flows are refined based on closure developments and regulatory or legal proceedings.
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) The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233 PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final 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 approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. 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. LKE recorded decreases of $66 million ( $56 million at KU and $10 million at LG&E) to the existing AROs during the three and six months ended June 30, 2017 related to the closure of CCR impoundments. These revisions are the result of changes in closure plans related to expected costs and timing of closures. Further changes to AROs, capital plans or operating costs may be required as estimates of future cash flows are refined based on closure developments and regulatory or legal proceedings.
Louisville Gas And Electric Co [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233 PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final 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 approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. 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. LKE recorded decreases of $66 million ( $56 million at KU and $10 million at LG&E) to the existing AROs during the three and six months ended June 30, 2017 related to the closure of CCR impoundments. These revisions are the result of changes in closure plans related to expected costs and timing of closures. Further changes to AROs, capital plans or operating costs may be required as estimates of future cash flows are refined based on closure developments and regulatory or legal proceedings.
Kentucky Utilities Co [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LKE, LG&E and KU) The changes in the carrying amounts of AROs were as follows. PPL LKE LG&E KU Balance at December 31, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233 PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final 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 approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. 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. LKE recorded decreases of $66 million ( $56 million at KU and $10 million at LG&E) to the existing AROs during the three and six months ended June 30, 2017 related to the closure of CCR impoundments. These revisions are the result of changes in closure plans related to expected costs and timing of closures. Further changes to AROs, capital plans or operating costs may be required as estimates of future cash flows are refined based on closure developments and regulatory or legal proceedings.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	6 Months Ended
	Jun. 30, 2017
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 June 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 March 31, 2017 $ (1,651 ) $ (14 ) $ (1 ) $ (8 ) $ (2,103 ) $ (3,777 ) Amounts arising during the period 231 (24 ) — — (11 ) 196 Reclassifications from AOCI — 25 1 1 31 58 Net OCI during the period 231 1 1 1 20 254 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 207 (30 ) — — (11 ) 166 Reclassifications from AOCI — 24 1 1 63 89 Net OCI during the period 207 (6 ) 1 1 52 255 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) March 31, 2016 $ (984 ) $ (5 ) $ — $ (6 ) $ (2,164 ) $ (3,159 ) Amounts arising during the period 268 (85 ) — — 2 185 Reclassifications from AOCI — 85 (1 ) 1 32 117 Net OCI during the period 268 — (1 ) 1 34 302 June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) December 31, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the period (196 ) (5 ) — — 2 (199 ) Reclassifications from AOCI — 7 (1 ) 1 63 70 Net OCI during the period (196 ) 2 (1 ) 1 65 (129 ) June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) LKE March 31, 2017 $ — $ (8 ) $ (60 ) $ (68 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 (10 ) (9 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI 1 1 2 4 Net OCI during the period 1 1 (9 ) (7 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) March 31, 2016 $ — $ (10 ) $ (35 ) $ (45 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 1 1 Net OCI during the period (1 ) 1 2 2 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 ) 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, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 2 2 Net OCI during the period (1 ) 1 3 3 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 ) (PPL) The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30 . The defined benefit plan components of AOCI are not reflected in their entirety in the Statement of Income during the periods; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 8 for additional information. Three Months Six Months Affected Line Item on the Details about AOCI 2017 2016 2017 2016 Statements of Income Qualifying derivatives Interest rate swaps $ (2 ) $ (2 ) $ (5 ) $ (3 ) Interest Expense Cross-currency swaps (29 ) (103 ) (26 ) (6 ) Other Income (Expense) - net (1 ) (1 ) — — Interest Expense Total Pre-tax (32 ) (106 ) (31 ) (9 ) Income Taxes 7 21 7 2 Total After-tax (25 ) (85 ) (24 ) (7 ) Equity investees' AOCI (1 ) 1 (1 ) 1 Other Income (Expense) - net Total Pre-tax (1 ) 1 (1 ) 1 Income Taxes — — — — Total After-tax (1 ) 1 (1 ) 1 Defined benefit plans Prior service costs (1 ) (1 ) (1 ) (1 ) Net actuarial loss (40 ) (40 ) (81 ) (80 ) Total Pre-tax (41 ) (41 ) (82 ) (81 ) Income Taxes 9 8 18 17 Total After-tax (32 ) (33 ) (64 ) (64 ) Total reclassifications during the period $ (58 ) $ (117 ) $ (89 ) $ (70 )
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 June 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 March 31, 2017 $ (1,651 ) $ (14 ) $ (1 ) $ (8 ) $ (2,103 ) $ (3,777 ) Amounts arising during the period 231 (24 ) — — (11 ) 196 Reclassifications from AOCI — 25 1 1 31 58 Net OCI during the period 231 1 1 1 20 254 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 207 (30 ) — — (11 ) 166 Reclassifications from AOCI — 24 1 1 63 89 Net OCI during the period 207 (6 ) 1 1 52 255 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) March 31, 2016 $ (984 ) $ (5 ) $ — $ (6 ) $ (2,164 ) $ (3,159 ) Amounts arising during the period 268 (85 ) — — 2 185 Reclassifications from AOCI — 85 (1 ) 1 32 117 Net OCI during the period 268 — (1 ) 1 34 302 June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) December 31, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the period (196 ) (5 ) — — 2 (199 ) Reclassifications from AOCI — 7 (1 ) 1 63 70 Net OCI during the period (196 ) 2 (1 ) 1 65 (129 ) June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) LKE March 31, 2017 $ — $ (8 ) $ (60 ) $ (68 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 (10 ) (9 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI 1 1 2 4 Net OCI during the period 1 1 (9 ) (7 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) March 31, 2016 $ — $ (10 ) $ (35 ) $ (45 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 1 1 Net OCI during the period (1 ) 1 2 2 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 ) 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, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 2 2 Net OCI during the period (1 ) 1 3 3 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 ) (PPL) The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30 . The defined benefit plan components of AOCI are not reflected in their entirety in the Statement of Income during the periods; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 8 for additional information. Three Months Six Months Affected Line Item on the Details about AOCI 2017 2016 2017 2016 Statements of Income Qualifying derivatives Interest rate swaps $ (2 ) $ (2 ) $ (5 ) $ (3 ) Interest Expense Cross-currency swaps (29 ) (103 ) (26 ) (6 ) Other Income (Expense) - net (1 ) (1 ) — — Interest Expense Total Pre-tax (32 ) (106 ) (31 ) (9 ) Income Taxes 7 21 7 2 Total After-tax (25 ) (85 ) (24 ) (7 ) Equity investees' AOCI (1 ) 1 (1 ) 1 Other Income (Expense) - net Total Pre-tax (1 ) 1 (1 ) 1 Income Taxes — — — — Total After-tax (1 ) 1 (1 ) 1 Defined benefit plans Prior service costs (1 ) (1 ) (1 ) (1 ) Net actuarial loss (40 ) (40 ) (81 ) (80 ) Total Pre-tax (41 ) (41 ) (82 ) (81 ) Income Taxes 9 8 18 17 Total After-tax (32 ) (33 ) (64 ) (64 ) Total reclassifications during the period $ (58 ) $ (117 ) $ (89 ) $ (70 )

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	6 Months Ended
	Jun. 30, 2017
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 Revenue from Contracts with Customers In May 2014, the Financial Accounting Standards Board (FASB) issued 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 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. For public business entities, this guidance can be applied using either a full retrospective or modified retrospective transition method, beginning in annual reporting periods after December 15, 2017 and interim periods within those years. The Registrants will adopt this guidance effective January 1, 2018. The Registrants have performed an assessment of a significant portion of their revenue under this new guidance to determine its effect on their current revenue recognition policies, and at this time they do not believe it will have a material impact. However, the Registrants will continue to monitor the development of industry specific application guidance which could have an impact on their assessments. The Registrants are currently assessing the disclosure requirements included in the standard, which will result in increased information being provided to enable the users of the financial statements to understand the nature, amount, timing and uncertainty of revenue arising from contracts with customers. The Registrants will determine the transition method they will apply after the industry specific application guidance is final and the implications of using either the full retrospective or modified retrospective transition methods are known. Accounting for Leases In February 2016, the 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 lines. 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 companies 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, and provides for certain practical expedients. Transition will require application of the new guidance at the beginning of the earliest comparative period presented. The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it. 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 in annual reporting periods 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. Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost In March 2017, the FASB issued accounting guidance that changes the income statement presentation of net periodic benefit cost. This new 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 will be presented separately from the line items that include the service cost and outside of any subtotal of operating income. Only the service cost component is eligible for capitalization. For public business entities, the guidance on the presentation of the components of net periodic benefit costs will be applied retrospectively. The guidance that limits the capitalization to the service cost component of net periodic benefit costs will be applied prospectively. This guidance is effective for fiscal years beginning after December 15, 2017 and interim periods within those years. The Registrants are currently assessing the impact of adopting this guidance and will adopt this guidance effective January 1, 2018. (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.

Summary of Significant Accoun27

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Receivables, Policy	Accounts Receivable (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.
Fair Value Transfer, Policy	Transfers between levels are recognized at end-of-reporting-period values.
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.
PPL Electric Utilities Corp [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Receivables, Policy	Accounts Receivable (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.

Segment and Related Informati28

Segment and Related Information (Tables)	6 Months Ended
	Jun. 30, 2017
Segment Reporting [Abstract]
Segment and Related Information	Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended June 30 are as follows: Three Months Six Months 2017 2016 2017 2016 Income Statement Data Revenues from external customers U.K. Regulated $ 502 $ 563 $ 1,070 $ 1,158 Kentucky Regulated 723 721 1,532 1,547 Pennsylvania Regulated 500 495 1,073 1,080 Corporate and Other — 6 1 11 Total $ 1,725 $ 1,785 $ 3,676 $ 3,796 Net Income U.K. Regulated (a) $ 148 $ 345 $ 434 $ 634 Kentucky Regulated 79 76 174 188 Pennsylvania Regulated 77 78 156 172 Corporate and Other (12 ) (16 ) (69 ) (30 ) Total $ 292 $ 483 $ 695 $ 964 (a) Includes unrealized gains and losses from hedging foreign-currency related economic activity. See Note 13 for additional information. Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: June 30, December 31, Balance Sheet Data Assets U.K. Regulated (a) $ 15,798 $ 14,537 Kentucky Regulated 14,043 14,037 Pennsylvania Regulated 10,175 9,426 Corporate and Other (b) (52 ) 315 Total $ 39,964 $ 38,315 (a) Includes $11.5 billion and $10.8 billion of net PP&E as of June 30, 2017 and December 31, 2016 . 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 and the elimination of inter-segment transactions.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2017
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 June 30 used in the EPS calculation are: Three Months Six Months 2017 2016 2017 2016 Income (Numerator) Net income $ 292 $ 483 $ 695 $ 964 Less amounts allocated to participating securities — 1 1 3 Net income available to PPL common shareowners - Basic and Diluted $ 292 $ 482 $ 694 $ 961 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 683,841 677,145 682,370 676,293 Add incremental non-participating securities: Share-based payment awards 2,510 3,584 2,355 3,480 Weighted-average shares - Diluted EPS 686,351 680,729 684,725 679,773 Basic EPS Net Income available to PPL common shareowners $ 0.43 $ 0.71 $ 1.02 $ 1.42 Diluted EPS Net Income available to PPL common shareowners $ 0.43 $ 0.71 $ 1.01 $ 1.41
Common Stock Issuances	For the periods ended June 30 , PPL issued common stock related to stock-based compensation plans and the DRIP as follows (in thousands): Three Months Six Months 2017 2016 2017 2016 Stock-based compensation plans (a) 564 795 1,451 2,920 DRIP 369 370 814 772 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.
Antidilutive Securities Excluded From Diluted EPS	For the periods ended June 30 , the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months Six Months 2017 2016 2017 2016 Stock options 696 696 696 696 Performance units — 78 — 39

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2017
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended June 30 are as follows. (PPL) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 129 $ 236 $ 315 $ 467 Increase (decrease) due to: State income taxes, net of federal income tax benefit 10 9 23 22 Valuation allowance adjustments — 3 5 9 Impact of lower U.K. income tax rates (40 ) (45 ) (88 ) (99 ) U.S. income tax on foreign earnings - net of foreign tax credit (a) (7 ) — (16 ) (2 ) Impact of the U.K. Finance Acts (6 ) (2 ) (9 ) (2 ) Depreciation not normalized (2 ) (3 ) (5 ) (4 ) Interest benefit on U.K. financing entities (4 ) (4 ) (8 ) (9 ) Stock-based compensation (4 ) (3 ) (7 ) (11 ) Other — 1 (5 ) — Total increase (decrease) (53 ) (44 ) (110 ) (96 ) Total income taxes $ 76 $ 192 $ 205 $ 371 (a) Lower income taxes primarily due to the tax benefit of accelerated pension contributions made in the first quarter of 2017. The related tax benefit is recognized over the annual period as a result of utilizing an estimated annual effective tax rate.
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended June 30 are as follows. (PPL Electric) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 44 $ 44 $ 88 $ 97 Increase (decrease) due to: State income taxes, net of federal income tax benefit 9 8 17 18 Depreciation not normalized (2 ) (2 ) (4 ) (3 ) Stock-based compensation (3 ) (2 ) (5 ) (7 ) Other (1 ) — (1 ) (1 ) Total increase (decrease) 3 4 7 7 Total income taxes $ 47 $ 48 $ 95 $ 104
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 June 30 are as follows. (LKE) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 49 $ 47 $ 107 $ 114 Increase (decrease) due to: State income taxes, net of federal income tax benefit 5 5 11 12 Other (1 ) (1 ) (2 ) (3 ) Total increase (decrease) 4 4 9 9 Total income taxes $ 53 $ 51 $ 116 $ 123
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 June 30 are as follows. (LG&E) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 24 $ 22 $ 55 $ 54 Increase (decrease) due to: State income taxes, net of federal income tax benefit 3 2 6 6 Other — — (1 ) (1 ) Total increase (decrease) 3 2 5 5 Total income taxes $ 27 $ 24 $ 60 $ 59
Kentucky Utilities Co [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income taxes for the periods ended June 30 are as follows. (KU) Three Months Six Months 2017 2016 2017 2016 Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 32 $ 31 $ 67 $ 73 Increase (decrease) due to: State income taxes, net of federal income tax benefit 3 3 7 7 Other (1 ) — (1 ) — Total increase (decrease) 2 3 6 7 Total income taxes $ 34 $ 34 $ 73 $ 80

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	6 Months Ended
	Jun. 30, 2017
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 June 30, December 31, June 30, December 31, Current Regulatory Assets: Environmental cost recovery $ 6 $ 6 $ — $ — Generation formula rate 10 11 — — Transmission service charge — 7 — 7 Gas supply clause 7 3 — — Smart meter rider 10 6 10 6 Storm costs 3 5 3 5 Other 1 1 1 1 Total current regulatory assets (a) $ 37 $ 39 $ 14 $ 19 Noncurrent Regulatory Assets: Defined benefit plans $ 920 $ 947 $ 537 $ 549 Taxes recoverable through future rates 345 340 345 340 Storm costs 40 58 — 10 Unamortized loss on debt 57 61 32 36 Interest rate swaps 124 129 — — Accumulated cost of removal of utility plant 162 159 162 159 AROs 245 211 — — Other 13 13 — — Total noncurrent regulatory assets $ 1,906 $ 1,918 $ 1,076 $ 1,094 PPL PPL Electric June 30, December 31, June 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 19 $ 23 $ 19 $ 23 Transmission service charge 6 — 6 — Universal service rider 14 14 14 14 Transmission formula rate 3 15 3 15 Fuel adjustment clause 13 11 — — Act 129 compliance rider 11 17 11 17 Storm damage expense 4 13 4 13 Other 1 8 — 1 Total current regulatory liabilities $ 71 $ 101 $ 57 $ 83 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 703 $ 700 $ — $ — Power purchase agreement - OVEC (b) 72 75 — — Net deferred tax assets 21 23 — — Defined benefit plans 27 23 — — Interest rate swaps 76 78 — — Other 3 — — — Total noncurrent regulatory liabilities $ 902 $ 899 $ — $ — LKE LG&E KU June 30, December 31, June 30, December 31, June 30, December 31, Current Regulatory Assets: Environmental cost recovery $ 6 $ 6 $ 4 $ 6 $ 2 $ — Generation formula rate 10 11 — — 10 11 Gas supply clause 7 3 7 3 — — Total current regulatory assets $ 23 $ 20 $ 11 $ 9 $ 12 $ 11 Noncurrent Regulatory Assets: Defined benefit plans $ 383 $ 398 $ 238 $ 246 $ 145 $ 152 Storm costs 40 48 22 26 18 22 Unamortized loss on debt 25 25 16 16 9 9 Interest rate swaps 124 129 85 88 39 41 AROs 245 211 84 70 161 141 Plant retirement costs 3 4 — — 3 4 Other 10 9 4 4 6 5 Total noncurrent regulatory assets $ 830 $ 824 $ 449 $ 450 $ 381 $ 374 LKE LG&E KU June 30, December 31, June 30, December 31, June 30, December 31, Current Regulatory Liabilities: Demand side management $ — $ 3 $ — $ 2 $ — $ 1 Fuel adjustment clause 13 11 4 2 9 9 Other 1 4 — 1 1 3 Total current regulatory liabilities $ 14 $ 18 $ 4 $ 5 $ 10 $ 13 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 703 $ 700 $ 308 $ 305 $ 395 $ 395 Power purchase agreement - OVEC (b) 72 75 50 52 22 23 Net deferred tax assets 21 23 21 23 — — Defined benefit plans 27 23 — — 27 23 Interest rate swaps 76 78 38 39 38 39 Other 3 — 1 — 2 — Total noncurrent regulatory liabilities $ 902 $ 899 $ 418 $ 419 $ 484 $ 480 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b) This liability was recorded as an offset to an intangible asset that was recorded at fair value upon the acquisition of LKE by PPL.

Financing Activities (Tables)

Financing Activities (Tables)	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The following credit facilities were in place at: June 30, 2017 December 31, 2016 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. 2022 £ 210 £ 155 £ — £ 56 £ 160 £ — Term Loan Facility (b) Dec. 2017 230 230 — — — — WPD (South West) Syndicated Credit Facility (c) July 2021 245 80 — 165 110 — WPD (East Midlands) Syndicated Credit Facility (d) July 2021 300 116 — 184 9 — WPD (West Midlands) Syndicated Credit Facility July 2021 300 — — 300 — — Uncommitted Credit Facilities (e) 90 50 4 36 60 4 Total U.K. Credit Facilities (f) £ 1,375 £ 631 £ 4 £ 741 £ 339 £ 4 June 30, 2017 December 31, 2016 Expiration Date Capacity Borrowed Letters of Credit and Commercial Paper Issued Unused Capacity Borrowed Letters of Credit and Commercial Paper Issued U.S. PPL Capital Funding Syndicated Credit Facility Jan. 2022 $ 950 $ — $ 424 $ 526 $ — $ 20 Syndicated Credit Facility Nov. 2018 300 — — 300 — — Bilateral Credit Facility Mar. 2018 150 — 17 133 — 17 Total PPL Capital Funding Credit Facilities $ 1,400 $ — $ 441 $ 959 $ — $ 37 PPL Electric Syndicated Credit Facility Jan. 2022 $ 650 $ — $ 1 $ 649 $ — $ 296 LKE Syndicated Credit Facility Oct. 2018 $ 75 $ — $ — $ 75 $ — $ — LG&E Syndicated Credit Facility Jan. 2022 $ 500 $ — $ 207 $ 293 $ — $ 169 KU Syndicated Credit Facility Jan. 2022 $ 400 $ — $ 51 $ 349 $ — $ 16 Letter of Credit Facility Oct. 2017 198 — 198 — — 198 Total KU Credit Facilities $ 598 $ — $ 249 $ 349 $ — $ 214 (a) The amounts borrowed at June 30, 2017 and December 31, 2016 were USD-denominated borrowings of $200 million for both periods, which bore interest at 1.87% and 1.43% . The unused capacity reflects the amount borrowed in GBP of £154 million as of the date borrowed. (b) The amount borrowed at June 30, 2017 was a GBP-denominated borrowing which equated to $297 million and bore interest at 1.50% . (c) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $103 million and $137 million and bore interest at 0.65% and 0.66% . (d) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $150 million and $11 million and bore interest at 0.65% and 0.66% . (e) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $65 million and $75 million and bore interest at 1.07% and 1.26% . (f) At June 30, 2017 , the unused capacity under the U.K. credit facilities was $956 million .
Schedule of Short-term Debt	The following commercial paper programs were in place at: June 30, 2017 December 31, 2016 Weighted - Average Interest Rate Capacity Commercial Paper Issuances Unused Capacity Weighted - Average Interest Rate Commercial Paper Issuances PPL Capital Funding 1.46% $ 1,000 $ 424 $ 576 1.10% $ 20 PPL Electric 650 — 650 1.05% 295 LG&E 1.35% 350 207 143 0.94% 169 KU 1.40% 350 51 299 0.87% 16 Total $ 2,350 $ 682 $ 1,668 $ 500
Schedule Of Stock Offering Program	For the periods ended June 30 , PPL issued the following: Three Months Six Months 2017 2016 2017 2016 Number of shares (in thousands) 2,113 — 3,477 — Average share price $ 39.15 $ — $ 38.17 $ — Net Proceeds $ 82 $ — $ 132 $ —

Defined Benefits (Tables)

Defined Benefits (Tables)	6 Months Ended
	Jun. 30, 2017
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 June 30 : Pension Benefits Three Months Six Months U.S. U.K. U.S. U.K. 2017 2016 2017 2016 2017 2016 2017 2016 PPL Service cost $ 15 $ 16 $ 18 $ 18 $ 32 $ 33 $ 37 $ 36 Interest cost 42 44 44 62 84 87 87 124 Expected return on plan assets (58 ) (58 ) (127 ) (132 ) (115 ) (114 ) (252 ) (265 ) Amortization of: Prior service cost 3 3 — — 5 4 — — Actuarial loss 14 10 36 36 34 25 71 73 Net periodic defined benefit costs (credits) before special termination benefits 16 15 (29 ) (16 ) 40 35 (57 ) (32 ) Special termination benefits (a) (1 ) — — — 1 — — — Net periodic defined benefit costs (credits) $ 15 $ 15 $ (29 ) $ (16 ) $ 41 $ 35 $ (57 ) $ (32 ) (a) 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 Six Months 2017 2016 2017 2016 LKE Service cost $ 5 $ 6 $ 12 $ 12 Interest cost 18 18 34 35 Expected return on plan assets (24 ) (24 ) (46 ) (45 ) Amortization of: Prior service cost 2 3 4 4 Actuarial loss 4 5 15 10 Net periodic defined benefit costs $ 5 $ 8 $ 19 $ 16 Pension Benefits Three Months Six Months 2017 2016 2017 2016 LG&E Service cost $ 1 $ 1 $ 1 $ 1 Interest cost 3 4 $ 6 $ 7 Expected return on plan assets (6 ) (5 ) (11 ) (10 ) Amortization of: Prior service cost 1 1 2 2 Actuarial loss 1 1 4 3 Net periodic defined benefit costs $ — $ 2 $ 2 $ 3 Other Postretirement Benefits Three Months Six Months 2017 2016 2017 2016 PPL Service cost $ 2 $ 2 $ 4 $ 4 Interest cost 6 7 12 13 Expected return on plan assets (5 ) (6 ) (11 ) (11 ) Amortization of prior service cost (1 ) — (1 ) — Net periodic defined benefit costs $ 2 $ 3 $ 4 $ 6 LKE Service cost $ 1 $ 1 $ 2 $ 2 Interest cost 2 3 4 5 Expected return on plan assets (2 ) (1 ) (3 ) (3 ) Amortization of prior service cost — — — 1 Net periodic defined benefit costs $ 1 $ 3 $ 3 $ 5
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 June 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 Six Months 2017 2016 2017 2016 PPL Electric $ 5 $ 5 $ 13 $ 11 LG&E 2 3 5 5 KU 1 3 5 6
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 June 30 : Pension Benefits Three Months Six Months U.S. U.K. U.S. U.K. 2017 2016 2017 2016 2017 2016 2017 2016 PPL Service cost $ 15 $ 16 $ 18 $ 18 $ 32 $ 33 $ 37 $ 36 Interest cost 42 44 44 62 84 87 87 124 Expected return on plan assets (58 ) (58 ) (127 ) (132 ) (115 ) (114 ) (252 ) (265 ) Amortization of: Prior service cost 3 3 — — 5 4 — — Actuarial loss 14 10 36 36 34 25 71 73 Net periodic defined benefit costs (credits) before special termination benefits 16 15 (29 ) (16 ) 40 35 (57 ) (32 ) Special termination benefits (a) (1 ) — — — 1 — — — Net periodic defined benefit costs (credits) $ 15 $ 15 $ (29 ) $ (16 ) $ 41 $ 35 $ (57 ) $ (32 ) (a) 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 Six Months 2017 2016 2017 2016 LKE Service cost $ 5 $ 6 $ 12 $ 12 Interest cost 18 18 34 35 Expected return on plan assets (24 ) (24 ) (46 ) (45 ) Amortization of: Prior service cost 2 3 4 4 Actuarial loss 4 5 15 10 Net periodic defined benefit costs $ 5 $ 8 $ 19 $ 16 Pension Benefits Three Months Six Months 2017 2016 2017 2016 LG&E Service cost $ 1 $ 1 $ 1 $ 1 Interest cost 3 4 $ 6 $ 7 Expected return on plan assets (6 ) (5 ) (11 ) (10 ) Amortization of: Prior service cost 1 1 2 2 Actuarial loss 1 1 4 3 Net periodic defined benefit costs $ — $ 2 $ 2 $ 3 Other Postretirement Benefits Three Months Six Months 2017 2016 2017 2016 PPL Service cost $ 2 $ 2 $ 4 $ 4 Interest cost 6 7 12 13 Expected return on plan assets (5 ) (6 ) (11 ) (11 ) Amortization of prior service cost (1 ) — (1 ) — Net periodic defined benefit costs $ 2 $ 3 $ 4 $ 6 LKE Service cost $ 1 $ 1 $ 2 $ 2 Interest cost 2 3 4 5 Expected return on plan assets (2 ) (1 ) (3 ) (3 ) Amortization of prior service cost — — — 1 Net periodic defined benefit costs $ 1 $ 3 $ 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 June 30 : Pension Benefits Three Months Six Months U.S. U.K. U.S. U.K. 2017 2016 2017 2016 2017 2016 2017 2016 PPL Service cost $ 15 $ 16 $ 18 $ 18 $ 32 $ 33 $ 37 $ 36 Interest cost 42 44 44 62 84 87 87 124 Expected return on plan assets (58 ) (58 ) (127 ) (132 ) (115 ) (114 ) (252 ) (265 ) Amortization of: Prior service cost 3 3 — — 5 4 — — Actuarial loss 14 10 36 36 34 25 71 73 Net periodic defined benefit costs (credits) before special termination benefits 16 15 (29 ) (16 ) 40 35 (57 ) (32 ) Special termination benefits (a) (1 ) — — — 1 — — — Net periodic defined benefit costs (credits) $ 15 $ 15 $ (29 ) $ (16 ) $ 41 $ 35 $ (57 ) $ (32 ) (a) 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 Six Months 2017 2016 2017 2016 LKE Service cost $ 5 $ 6 $ 12 $ 12 Interest cost 18 18 34 35 Expected return on plan assets (24 ) (24 ) (46 ) (45 ) Amortization of: Prior service cost 2 3 4 4 Actuarial loss 4 5 15 10 Net periodic defined benefit costs $ 5 $ 8 $ 19 $ 16 Pension Benefits Three Months Six Months 2017 2016 2017 2016 LG&E Service cost $ 1 $ 1 $ 1 $ 1 Interest cost 3 4 $ 6 $ 7 Expected return on plan assets (6 ) (5 ) (11 ) (10 ) Amortization of: Prior service cost 1 1 2 2 Actuarial loss 1 1 4 3 Net periodic defined benefit costs $ — $ 2 $ 2 $ 3 Other Postretirement Benefits Three Months Six Months 2017 2016 2017 2016 PPL Service cost $ 2 $ 2 $ 4 $ 4 Interest cost 6 7 12 13 Expected return on plan assets (5 ) (6 ) (11 ) (11 ) Amortization of prior service cost (1 ) — (1 ) — Net periodic defined benefit costs $ 2 $ 3 $ 4 $ 6 LKE Service cost $ 1 $ 1 $ 2 $ 2 Interest cost 2 3 4 5 Expected return on plan assets (2 ) (1 ) (3 ) (3 ) Amortization of prior service cost — — — 1 Net periodic defined benefit costs $ 1 $ 3 $ 3 $ 5
Allocation of Net Periodic Benefit Costs	For the periods ended June 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 Six Months 2017 2016 2017 2016 PPL Electric $ 5 $ 5 $ 13 $ 11 LG&E 2 3 5 5 KU 1 3 5 6
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 June 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 Six Months 2017 2016 2017 2016 PPL Electric $ 5 $ 5 $ 13 $ 11 LG&E 2 3 5 5 KU 1 3 5 6

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Guarantees	The table below details guarantees provided as of June 30, 2017 . Exposure at Expiration PPL Indemnifications related to the WPD Midlands acquisition (a) WPD indemnifications for entities in liquidation and sales of assets $ 10 (b) 2019 WPD guarantee of pension and other obligations of unconsolidated entities 92 (c) PPL Electric Guarantee of inventory value 15 (d) 2018 LKE Indemnification of lease termination and other divestitures 301 (e) 2021 - 2023 LG&E and KU LG&E and KU guarantee of shortfall related to OVEC (f) (a) (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 June 30, 2017 , 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. Another WKE-related LKE guarantee covers other indemnifications related to the purchase price of excess power, has a term expiring in 2023, and a maximum exposure of $100 million . In May 2012, LKE's indemnitee received an unfavorable arbitration panel's decision interpreting this matter. In October 2014, LKE's indemnitee filed a motion for discretionary review with the Kentucky Supreme Court seeking to overturn the arbitration decision, and such motion was denied by the court in September 2015. In September 2015, the counterparty issued a demand letter to LKE's indemnitee. In February 2016, the counterparty filed a complaint in Henderson, Kentucky Circuit Court, seeking an award of damages in the matter. The proceeding is currently in the discovery phase. LKE does not believe appropriate contractual, legal or commercial grounds exist for the claim made. LKE believes its indemnification obligations in the WKE matter remain subject to various uncertainties, including additional legal and contractual developments, as well as future prices, availability and demand for the subject excess power. Although the parties have also conducted certain settlement discussions, the ultimate outcomes of the WKE termination-related indemnifications cannot be predicted at this time. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant losses above the amounts recorded. (f) Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. LKE's proportionate share of OVEC's outstanding debt was $120 million at June 30, 2017 , consisting of LG&E's share of $83 million and KU's share of $37 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 2016 Form 10-K for additional information on the OVEC power purchase contract. In connection with recent credit market related developments at OVEC or certain of its sponsors, such parties, 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 and accelerated maturities of OVEC's existing short and long-term debt. The ultimate outcome of these matters, including any 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)	6 Months Ended
	Jun. 30, 2017
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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105
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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105
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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105
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 June 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 Six Months 2017 2016 2017 2016 PPL Electric from PPL Services $ 44 $ 28 $ 95 $ 65 LKE from PPL Services 5 4 11 9 PPL Electric from PPL EU Services 15 16 33 33 LG&E from LKS 38 41 82 88 KU from LKS 47 49 91 105

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were: June 30, 2017 December 31, 2016 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 467 $ 467 $ — $ — $ 341 $ 341 $ — $ — Restricted cash and cash equivalents (a) 25 25 — — 26 26 — — Price risk management assets (b): Foreign currency contracts 156 — 156 — 211 — 211 — Cross-currency swaps 158 — 158 — 188 — 188 — Total price risk management assets 314 — 314 — 399 — 399 — Total assets $ 806 $ 492 $ 314 $ — $ 766 $ 367 $ 399 $ — Liabilities Price risk management liabilities (b): Interest rate swaps $ 31 $ — $ 31 $ — $ 31 $ — $ 31 $ — Foreign currency contracts 104 — 104 — 27 — 27 — Total price risk management liabilities $ 135 $ — $ 135 $ — $ 58 $ — $ 58 $ — PPL Electric Assets Cash and cash equivalents $ 59 $ 59 $ — $ — $ 13 $ 13 $ — $ — Restricted cash and cash equivalents (a) 2 2 — — 2 2 — — Total assets $ 61 $ 61 $ — $ — $ 15 $ 15 $ — $ — LKE Assets Cash and cash equivalents $ 19 $ 19 $ — $ — $ 13 $ 13 $ — $ — Cash collateral posted to counterparties (c) 2 2 — — 3 3 — — Total assets $ 21 $ 21 $ — $ — $ 16 $ 16 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — Total price risk management liabilities $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — LG&E Assets Cash and cash equivalents $ 7 $ 7 $ — $ — $ 5 $ 5 $ — $ — Cash collateral posted to counterparties (c) 2 2 — — 3 3 — — Total assets $ 9 $ 9 $ — $ — $ 8 $ 8 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — Total price risk management liabilities $ 30 $ — $ 30 $ — $ 31 $ — $ 31 $ — June 30, 2017 December 31, 2016 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 KU Assets Cash and cash equivalents $ 12 $ 12 $ — $ — $ 7 $ 7 $ — $ — Total assets $ 12 $ 12 $ — $ — $ 7 $ 7 $ — $ — (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. (c) Included in "Other noncurrent assets" on the Balance Sheets. Represents cash collateral posted to offset the exposure with counterparties related to certain interest rate swaps under master netting arrangements that are not offset.
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. June 30, 2017 December 31, 2016 Carrying Amount (a) Fair Value Carrying Amount (a) Fair Value PPL $ 19,068 $ 22,791 $ 18,326 $ 21,355 PPL Electric 3,298 3,705 2,831 3,148 LKE 5,067 5,535 5,065 5,439 LG&E 1,619 1,749 1,617 1,710 KU 2,327 2,572 2,327 2,514 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He37

Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2017
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. June 30, 2017 December 31, 2016 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) $ — $ 1 $ — $ 5 $ — $ — $ — $ 4 Cross-currency swaps (b) 28 — — — 32 — — — Foreign currency contracts — — 41 60 — — 31 21 Total current 28 1 41 65 32 — 31 25 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 25 — — — 27 Cross-currency swaps (b) 130 — — — 156 — — — Foreign currency contracts — — 115 44 — — 180 6 Total noncurrent 130 — 115 69 156 — 180 33 Total derivatives $ 158 $ 1 $ 156 $ 134 $ 188 $ — $ 211 $ 58 (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 June 30, 2017 . Three Months Six Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Six Months Cash Flow Hedges: Interest rate swaps $ (2 ) $ (2 ) Interest expense $ (2 ) $ — $ (4 ) $ (1 ) Cross-currency swaps (27 ) (35 ) Interest expense (1 ) — — — Other income (expense) - net (29 ) — (26 ) — Total $ (29 ) $ (37 ) $ (32 ) $ — $ (30 ) $ (1 ) Net Investment Hedges: Foreign currency contracts $ — $ — Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Six Months Foreign currency contracts Other income (expense) - net $ (113 ) $ (156 ) Interest rate swaps Interest expense (1 ) (3 ) Total $ (114 ) $ (159 ) Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 1 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 June 30, 2016 . Three Months Six Months Derivative Derivative Gain (Loss) Recognized in OCI (Effective Portion) Location of Gain (Loss) Gain (Loss) Gain (Loss) Gain (Loss) Three Months Six Months Cash Flow Hedges: Interest rate swaps $ (3 ) $ (21 ) Interest expense $ (2 ) $ — $ (3 ) $ — Cross-currency swaps (104 ) 9 Interest expense (1 ) — — — Other income (expense) - net (103 ) — (6 ) — Total $ (107 ) $ (12 ) $ (106 ) $ — $ (9 ) $ — Net Investment Hedges: Foreign currency contracts $ 1 $ 4 Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative Three Months Six Months Foreign currency contracts Other income (expense) - net $ 171 $ 231 Interest rate swaps Interest expense (2 ) (4 ) Total $ 169 $ 227 Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (3 ) $ (9 )
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net June 30, 2017 Treasury Derivatives PPL $ 314 $ 93 $ 27 $ 194 $ 135 $ 93 $ 2 $ 40 LKE — — — — 30 — 2 28 LG&E — — — — 30 — 2 28 December 31, 2016 Treasury Derivatives PPL $ 399 $ 27 $ 19 $ 353 $ 58 $ 27 $ 3 $ 28 LKE — — — — 31 — 3 28 LG&E — — — — 31 — 3 28
Credit Risk-Related Contingent Features	At June 30, 2017 , 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 $ 23 $ 12 $ 12 Aggregate fair value of collateral posted on these derivative instruments 2 2 2 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 21 10 10 (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. June 30, 2017 December 31, 2016 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 5 $ — $ 4 Total current — 5 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 25 — 27 Total noncurrent — 25 — 27 Total derivatives $ — $ 30 $ — $ 31
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 June 30, 2017 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Six Months Interest rate swaps Interest expense $ (1 ) $ (3 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 1 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 June 30, 2016 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Six Months Interest rate swaps Interest expense $ (2 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (3 ) $ (9 )
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net June 30, 2017 Treasury Derivatives PPL $ 314 $ 93 $ 27 $ 194 $ 135 $ 93 $ 2 $ 40 LKE — — — — 30 — 2 28 LG&E — — — — 30 — 2 28 December 31, 2016 Treasury Derivatives PPL $ 399 $ 27 $ 19 $ 353 $ 58 $ 27 $ 3 $ 28 LKE — — — — 31 — 3 28 LG&E — — — — 31 — 3 28
Credit Risk-Related Contingent Features	At June 30, 2017 , 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 $ 23 $ 12 $ 12 Aggregate fair value of collateral posted on these derivative instruments 2 2 2 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 21 10 10 (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. June 30, 2017 December 31, 2016 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 5 $ — $ 4 Total current — 5 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 25 — 27 Total noncurrent — 25 — 27 Total derivatives $ — $ 30 $ — $ 31
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 June 30, 2017 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Six Months Interest rate swaps Interest expense $ (1 ) $ (3 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (1 ) $ 1 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 June 30, 2016 . Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Six Months Interest rate swaps Interest expense $ (2 ) $ (4 ) Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Six Months Interest rate swaps Regulatory assets - noncurrent $ (3 ) $ (9 )
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net June 30, 2017 Treasury Derivatives PPL $ 314 $ 93 $ 27 $ 194 $ 135 $ 93 $ 2 $ 40 LKE — — — — 30 — 2 28 LG&E — — — — 30 — 2 28 December 31, 2016 Treasury Derivatives PPL $ 399 $ 27 $ 19 $ 353 $ 58 $ 27 $ 3 $ 28 LKE — — — — 31 — 3 28 LG&E — — — — 31 — 3 28
Credit Risk-Related Contingent Features	At June 30, 2017 , 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 $ 23 $ 12 $ 12 Aggregate fair value of collateral posted on these derivative instruments 2 2 2 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 21 10 10 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.
Kentucky Utilities Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Instruments Cash Collateral Received Net Gross Derivative Instruments Cash Collateral Pledged Net June 30, 2017 Treasury Derivatives PPL $ 314 $ 93 $ 27 $ 194 $ 135 $ 93 $ 2 $ 40 LKE — — — — 30 — 2 28 LG&E — — — — 30 — 2 28 December 31, 2016 Treasury Derivatives PPL $ 399 $ 27 $ 19 $ 353 $ 58 $ 27 $ 3 $ 28 LKE — — — — 31 — 3 28 LG&E — — — — 31 — 3 28

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233
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, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233
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, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233
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, 2016 $ 488 $ 433 $ 145 $ 288 Accretion 11 10 4 6 Effect of foreign exchange rates 2 — — — Changes in estimated timing or cost (73 ) (66 ) (10 ) (56 ) Obligations settled (12 ) (12 ) (7 ) (5 ) Balance at June 30, 2017 $ 416 $ 365 $ 132 $ 233

Accumulated Other Comprehensi39

Accumulated Other Comprehensive Income (Loss) (Tables)	6 Months Ended
	Jun. 30, 2017
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 June 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 March 31, 2017 $ (1,651 ) $ (14 ) $ (1 ) $ (8 ) $ (2,103 ) $ (3,777 ) Amounts arising during the period 231 (24 ) — — (11 ) 196 Reclassifications from AOCI — 25 1 1 31 58 Net OCI during the period 231 1 1 1 20 254 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 207 (30 ) — — (11 ) 166 Reclassifications from AOCI — 24 1 1 63 89 Net OCI during the period 207 (6 ) 1 1 52 255 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) March 31, 2016 $ (984 ) $ (5 ) $ — $ (6 ) $ (2,164 ) $ (3,159 ) Amounts arising during the period 268 (85 ) — — 2 185 Reclassifications from AOCI — 85 (1 ) 1 32 117 Net OCI during the period 268 — (1 ) 1 34 302 June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) December 31, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the period (196 ) (5 ) — — 2 (199 ) Reclassifications from AOCI — 7 (1 ) 1 63 70 Net OCI during the period (196 ) 2 (1 ) 1 65 (129 ) June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) LKE March 31, 2017 $ — $ (8 ) $ (60 ) $ (68 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 (10 ) (9 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI 1 1 2 4 Net OCI during the period 1 1 (9 ) (7 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) March 31, 2016 $ — $ (10 ) $ (35 ) $ (45 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 1 1 Net OCI during the period (1 ) 1 2 2 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 ) 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, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 2 2 Net OCI during the period (1 ) 1 3 3 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 )
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 June 30 . Three Months Six Months Affected Line Item on the Details about AOCI 2017 2016 2017 2016 Statements of Income Qualifying derivatives Interest rate swaps $ (2 ) $ (2 ) $ (5 ) $ (3 ) Interest Expense Cross-currency swaps (29 ) (103 ) (26 ) (6 ) Other Income (Expense) - net (1 ) (1 ) — — Interest Expense Total Pre-tax (32 ) (106 ) (31 ) (9 ) Income Taxes 7 21 7 2 Total After-tax (25 ) (85 ) (24 ) (7 ) Equity investees' AOCI (1 ) 1 (1 ) 1 Other Income (Expense) - net Total Pre-tax (1 ) 1 (1 ) 1 Income Taxes — — — — Total After-tax (1 ) 1 (1 ) 1 Defined benefit plans Prior service costs (1 ) (1 ) (1 ) (1 ) Net actuarial loss (40 ) (40 ) (81 ) (80 ) Total Pre-tax (41 ) (41 ) (82 ) (81 ) Income Taxes 9 8 18 17 Total After-tax (32 ) (33 ) (64 ) (64 ) Total reclassifications during the period $ (58 ) $ (117 ) $ (89 ) $ (70 )
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 June 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 March 31, 2017 $ (1,651 ) $ (14 ) $ (1 ) $ (8 ) $ (2,103 ) $ (3,777 ) Amounts arising during the period 231 (24 ) — — (11 ) 196 Reclassifications from AOCI — 25 1 1 31 58 Net OCI during the period 231 1 1 1 20 254 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) December 31, 2016 $ (1,627 ) $ (7 ) $ (1 ) $ (8 ) $ (2,135 ) $ (3,778 ) Amounts arising during the period 207 (30 ) — — (11 ) 166 Reclassifications from AOCI — 24 1 1 63 89 Net OCI during the period 207 (6 ) 1 1 52 255 June 30, 2017 $ (1,420 ) $ (13 ) $ — $ (7 ) $ (2,083 ) $ (3,523 ) March 31, 2016 $ (984 ) $ (5 ) $ — $ (6 ) $ (2,164 ) $ (3,159 ) Amounts arising during the period 268 (85 ) — — 2 185 Reclassifications from AOCI — 85 (1 ) 1 32 117 Net OCI during the period 268 — (1 ) 1 34 302 June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) December 31, 2015 $ (520 ) $ (7 ) $ — $ (6 ) $ (2,195 ) $ (2,728 ) Amounts arising during the period (196 ) (5 ) — — 2 (199 ) Reclassifications from AOCI — 7 (1 ) 1 63 70 Net OCI during the period (196 ) 2 (1 ) 1 65 (129 ) June 30, 2016 $ (716 ) $ (5 ) $ (1 ) $ (5 ) $ (2,130 ) $ (2,857 ) LKE March 31, 2017 $ — $ (8 ) $ (60 ) $ (68 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI — 1 1 2 Net OCI during the period — 1 (10 ) (9 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) December 31, 2016 $ (1 ) $ (8 ) $ (61 ) $ (70 ) Amounts arising during the period — — (11 ) (11 ) Reclassifications from AOCI 1 1 2 4 Net OCI during the period 1 1 (9 ) (7 ) June 30, 2017 $ — $ (7 ) $ (70 ) $ (77 ) March 31, 2016 $ — $ (10 ) $ (35 ) $ (45 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 1 1 Net OCI during the period (1 ) 1 2 2 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 ) 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, 2015 $ — $ (10 ) $ (36 ) $ (46 ) Amounts arising during the period — — 1 1 Reclassifications from AOCI (1 ) 1 2 2 Net OCI during the period (1 ) 1 3 3 June 30, 2016 $ (1 ) $ (9 ) $ (33 ) $ (43 )

Summary of Significant Accoun40

Summary of Significant Accounting Policies (Details) - Alternative Electricity Suppliers [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable	$ 288	$ 297	$ 644	$ 679
PPL Electric Utilities Corp [Member]
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable	$ 288	$ 297	$ 644	$ 679

Segment and Related Informati41

Segment and Related Information (Details) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)Integer	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)
Income Statement Data [Abstract]
Revenues from external customers		$ 1,725	$ 1,785	$ 3,676	$ 3,796
Net Income		292	483	695	964
Balance Sheet Data [Abstract]
Assets		39,964		39,964		$ 38,315
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Revenues from external customers		500	495	1,073	1,080
Net Income	[1]	77	79	156	173
Balance Sheet Data [Abstract]
Assets		10,175		$ 10,175		9,426
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]
Revenues from external customers		723	721	$ 1,532	1,547
Net Income		87	84	190	204
Balance Sheet Data [Abstract]
Assets		14,377		$ 14,377		14,371
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]
Revenues from external customers		324	323	$ 715	709
Net Income	[1]	42	40	96	96
Balance Sheet Data [Abstract]
Assets		6,294		$ 6,294		6,300
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Revenues from external customers		406	407	$ 843	860
Net Income	[2]	56	54	119	129
Balance Sheet Data [Abstract]
Assets		8,086		$ 8,086		8,085
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
United Kingdom Regulated [Member]
Income Statement Data [Abstract]
Revenues from external customers		502	563	$ 1,070	1,158
Net Income		148	345	434	634
Balance Sheet Data [Abstract]
Assets		15,798		15,798		14,537
Segment (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		11,500		11,500		10,800
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Revenues from external customers		723	721	1,532	1,547
Net Income		79	76	174	188
Balance Sheet Data [Abstract]
Assets		14,043		14,043		14,037
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Revenues from external customers		500	495	1,073	1,080
Net Income		77	78	156	172
Balance Sheet Data [Abstract]
Assets		10,175		10,175		9,426
Corporate And Other [Member]
Income Statement Data [Abstract]
Revenues from external customers		0	6	1	11
Net Income		(12)	$ (16)	(69)	$ (30)
Balance Sheet Data [Abstract]
Assets		$ (52)		$ (52)		$ 315
[1]	Net income equals comprehensive income.
[2]	Net income approximates comprehensive income.

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Income (Numerator) [Abstract]
Net Income	$ 292	$ 483	$ 695	$ 964
Less amounts allocated to participating securities	0	1	1	3
Net income available to PPL common shareowners - Basic	292	482	694	961
Net income available to PPL common shareowners - Diluted	$ 292	$ 482	$ 694	$ 961
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	683,841	677,145	682,370	676,293
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	2,510	3,584	2,355	3,480
Weighted-average shares - Diluted EPS (in shares)	686,351	680,729	684,725	679,773
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.43	$ 0.71	$ 1.02	$ 1.42
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.43	$ 0.71	$ 1.01	$ 1.41
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	564	795	1,451	2,920
Common stock issued under dividend reinvestment plan (in shares)	369	370	814	772
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	696	696	696	696
Performance units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	0	78	0	39

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 129	$ 236	$ 315	$ 467
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 10	$ 9	$ 23	$ 22
Valuation allowance adjustments	0	3	5	9
Impact of lower U.K. income tax rates	(40)	(45)	(88)	(99)
U.S. income tax on foreign earnings - net of foreign tax credit	(7)	0	(16)	(2)
Impact of the U.K. Finance Acts	(6)	(2)	(9)	(2)
Depreciation not normalized	(2)	(3)	(5)	(4)
Interest benefit on U.K. financing entities	(4)	(4)	(8)	(9)
Stock-based compensation	(4)	(3)	(7)	(11)
Other	0	1	(5)	0
Total increase (decrease)	(53)	(44)	(110)	(96)
Total income taxes	76	192	205	371
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 44	$ 44	$ 88	$ 97
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 9	$ 8	$ 17	$ 18
Depreciation not normalized	(2)	(2)	(4)	(3)
Stock-based compensation	(3)	(2)	(5)	(7)
Other	(1)	0	(1)	(1)
Total increase (decrease)	3	4	7	7
Total income taxes	47	48	95	104
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 - 35%	$ 49	$ 47	$ 107	$ 114
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 5	$ 5	$ 11	$ 12
Other	(1)	(1)	(2)	(3)
Total increase (decrease)	4	4	9	9
Total income taxes	53	51	116	123
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 24	$ 22	$ 55	$ 54
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 3	$ 2	$ 6	$ 6
Other	0	0	(1)	(1)
Total increase (decrease)	3	2	5	5
Total income taxes	27	24	60	59
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 32	$ 31	$ 67	$ 73
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 3	$ 3	$ 7	$ 7
Other	(1)	0	(1)	0
Total increase (decrease)	2	3	6	7
Total income taxes	$ 34	$ 34	$ 73	$ 80

Utility Rate Regulation - Regul

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Regulatory Assets [Line Items]
Current regulatory assets	$ 37	$ 39
Noncurrent regulatory assets	1,906	1,918
Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	11
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	7
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	6
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	920	947
Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	345	340
Storm Costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	5
Noncurrent regulatory assets	40	58
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	57	61
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	124	129
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	162	159
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	245	211
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	1
Noncurrent regulatory assets	13	13
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	14	19
Noncurrent regulatory assets	1,076	1,094
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] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	7
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	6
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	537	549
PPL Electric Utilities Corp [Member] | Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	345	340
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	5
Noncurrent regulatory assets	0	10
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	32	36
PPL Electric Utilities Corp [Member] | 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	162	159
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	1
Noncurrent regulatory assets	0	0
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current regulatory assets	23	20
Noncurrent regulatory assets	830	824
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
LG And E And KU Energy LLC [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	11
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	383	398
LG And E And KU Energy LLC [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	40	48
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	25	25
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	124	129
LG And E And KU Energy LLC [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	245	211
LG And E And KU Energy LLC [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	4
LG And E And KU Energy LLC [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	10	9
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	11	9
Noncurrent regulatory assets	449	450
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	6
Louisville Gas And Electric Co [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	238	246
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	26
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	16	16
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	85	88
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	84	70
Louisville Gas And Electric Co [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	4	4
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	12	11
Noncurrent regulatory assets	381	374
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	2	0
Kentucky Utilities Co [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	11
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	145	152
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	18	22
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	39	41
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	161	141
Kentucky Utilities Co [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	4
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 6	$ 5

Utility Rate Regulation - Reg45

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 71	$ 101
Noncurrent regulatory liabilities	902	899
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	19	23
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	14
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	15
Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	13	11
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	17
Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	13
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	703	700
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	75
Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	23
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	23
Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	76	78
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	8
Noncurrent regulatory liabilities	3	0
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	57	83
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	19	23
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	14
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	15
PPL Electric Utilities Corp [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	17
PPL Electric Utilities Corp [Member] | Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	13
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 Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | 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	1
Noncurrent regulatory liabilities	0	0
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	18
Noncurrent regulatory liabilities	902	899
LG And E And KU Energy LLC [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	13	11
LG And E And KU Energy LLC [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	703	700
LG And E And KU Energy LLC [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	75
LG And E And KU Energy LLC [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	23
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	23
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	76	78
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	4
Noncurrent regulatory liabilities	3	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	5
Noncurrent regulatory liabilities	418	419
Louisville Gas And Electric Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	2
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	2
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	308	305
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	50	52
Louisville Gas And Electric Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	23
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] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	38	39
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
Noncurrent regulatory liabilities	1	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	10	13
Noncurrent regulatory liabilities	484	480
Kentucky Utilities Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	9	9
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	395	395
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	22	23
Kentucky Utilities Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	23
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	38	39
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	3
Noncurrent regulatory liabilities	$ 2	$ 0

Utility Rate Regulation - Reg46

Utility Rate Regulation - Regulatory Matters (Details) - USD ($) $ in Millions	Jun. 29, 2017	Jun. 23, 2017	Apr. 19, 2017	Aug. 31, 2016
LKE [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 15
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 59
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 57
Public Utilities, Approved Rate Increase (Decrease), Percentage	5.20%
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 8
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 7
Public Utilities, Approved Rate Increase (Decrease), Percentage	2.10%
LGE [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 4
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 55
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 52
Public Utilities, Approved Rate Increase (Decrease), Percentage	3.20%
KU [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 11
KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 15
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, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
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, Proposed Rate Increase (Decrease), Amount			$ 59
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 57
Public Utilities, Approved Rate Increase (Decrease), Percentage	5.20%
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, Proposed Rate Increase (Decrease), Amount			$ 8
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 7
Public Utilities, Approved Rate Increase (Decrease), Percentage	2.10%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
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, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
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, Proposed Rate Increase (Decrease), Amount			$ 55
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 52
Public Utilities, Approved Rate Increase (Decrease), Percentage	3.20%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
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%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
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, Proposed Rate Increase (Decrease), Amount			$ 59
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 57
Public Utilities, Approved Rate Increase (Decrease), Percentage	5.20%
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, Proposed Rate Increase (Decrease), Amount			$ 8
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 7
Public Utilities, Approved Rate Increase (Decrease), Percentage	2.10%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 4
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 55
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 52
Public Utilities, Approved Rate Increase (Decrease), Percentage	3.20%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 11
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	1 Months Ended	6 Months Ended
	Aug. 31, 2017	Jun. 30, 2017USD ($)	Jun. 30, 2017GBP (£)	Dec. 31, 2016USD ($)	Dec. 31, 2016GBP (£)
UNITED KINGDOM
Line of Credit Facility [Line Items]
Capacity | £			£ 1,375
Borrowed | £			631		£ 339
Letters of Credit and Commercial Paper Issued | £			4		4
Unused Capacity		$ 956	741
UNITED KINGDOM | Uncommitted Credit Facilities [Member]
Line of Credit Facility [Line Items]
Capacity | £			90
Borrowed		$ 65	50	$ 75	60
Letters of Credit and Commercial Paper Issued | £			4		£ 4
Unused Capacity | £			£ 36
Interest rate on outstanding borrowing		1.07%	1.07%	1.26%	1.26%
WPD PLC [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 13, 2022
Capacity | £			£ 210
Borrowed		$ 200	155	$ 200	£ 160
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 56
Interest rate on outstanding borrowing		1.87%	1.87%	1.43%	1.43%
Borrowed | £			£ 154
WPD PLC [Member] | UNITED KINGDOM | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Dec. 28, 2017
Capacity | £			230
Borrowed		$ 297	230		£ 0
Letters of Credit and Commercial Paper Issued | £			0		0
Unused Capacity | £			£ 0
Interest rate on outstanding borrowing		1.50%	1.50%
WPD South West [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jul. 29, 2021
Capacity | £			£ 245
Borrowed		$ 103	80	$ 137	110
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 165
Interest rate on outstanding borrowing		0.65%	0.65%	0.66%	0.66%
WPD East Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jul. 29, 2021
Capacity | £			£ 300
Borrowed		$ 150	116	$ 11	£ 9
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 184
Interest rate on outstanding borrowing		0.65%	0.65%	0.66%	0.66%
WPD West Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jul. 29, 2021
Capacity | £			£ 300
Borrowed | £			0		£ 0
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 300
PPL Capital Funding [Member] | UNITED STATES
Line of Credit Facility [Line Items]
Capacity		$ 1,400
Borrowed		0		$ 0
Letters of Credit and Commercial Paper Issued		441		37
Unused Capacity		$ 959
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 27, 2022
Capacity		$ 950
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		424		20
Unused Capacity		$ 526
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Nov. 12, 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. 16, 2018
Capacity		$ 150
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		17		17
Unused Capacity		$ 133
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 27, 2022
Capacity		$ 650
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		1		296
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] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 500
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		207		169
Unused Capacity		293
KU [Member]
Line of Credit Facility [Line Items]
Capacity		598
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		249		214
Unused Capacity		$ 349
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 400
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		51		16
Unused Capacity		$ 349
KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Oct. 1, 2017
Capacity		$ 198
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		198		198
Unused Capacity		$ 0
KU [Member] | Letter Of Credit Facility [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 1, 2020
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 27, 2022
Capacity		$ 650
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		1		296
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] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 500
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		207		169
Unused Capacity		293
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		249		214
Unused Capacity		$ 349
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 400
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		51		16
Unused Capacity		$ 349
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Oct. 1, 2017
Capacity		$ 198
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		198		198
Unused Capacity		$ 0
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 1, 2020
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 500
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		207		169
Unused Capacity		293
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity		598
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		249		214
Unused Capacity		$ 349
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 400
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		51		16
Unused Capacity		$ 349
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Oct. 1, 2017
Capacity		$ 198
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		198		$ 198
Unused Capacity		$ 0
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 1, 2020

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Short-term Debt [Line Items]
Capacity	$ 2,350
Commercial Paper Issuances	682	$ 500
Unused Capacity	$ 1,668
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.46%	1.10%
Capacity	$ 1,000
Commercial Paper Issuances	424	$ 20
Unused Capacity	$ 576
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		1.05%
Capacity	$ 650
Commercial Paper Issuances	0	$ 295
Unused Capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.35%	0.94%
Capacity	$ 350
Commercial Paper Issuances	207	$ 169
Unused Capacity	$ 143
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.40%	0.87%
Capacity	$ 350
Commercial Paper Issuances	51	$ 16
Unused Capacity	$ 299
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		1.05%
Capacity	$ 650
Commercial Paper Issuances	0	$ 295
Unused Capacity	$ 650
LG And E And KU Energy LLC [Member] | LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.35%	0.94%
Capacity	$ 350
Commercial Paper Issuances	207	$ 169
Unused Capacity	$ 143
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.40%	0.87%
Capacity	$ 350
Commercial Paper Issuances	51	$ 16
Unused Capacity	$ 299
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.35%	0.94%
Capacity	$ 350
Commercial Paper Issuances	207	$ 169
Unused Capacity	$ 143
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.40%	0.87%
Capacity	$ 350
Commercial Paper Issuances	51	$ 16
Unused Capacity	$ 299

Financing Activities - Long-ter

Financing Activities - Long-term Debt and ATM Program (Details) $ / shares in Units, shares in Thousands, £ in Millions, $ in Millions	1 Months Ended						3 Months Ended		6 Months Ended
	Jun. 30, 2017USD ($)	May 31, 2017USD ($)	Apr. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Mar. 31, 2017GBP (£)	Feb. 28, 2015USD ($)Integer	Jun. 30, 2017USD ($)$ / sharesshares	Jun. 30, 2016USD ($)$ / sharesshares	Jun. 30, 2017USD ($)$ / sharesshares	Jun. 30, 2016USD ($)$ / sharesshares
At-the-Market Stock Offering Program (Numeric) [Abstract]
Net proceeds from issuance of common stock									$ 177	$ 76
WPD South Wales PLC [Member] | Index Linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £					£ 50
Stated interest rate					0.01%
Proceeds from debt, net of issuance costs | £					£ 53
Maturity date				Mar. 14, 2029	Mar. 14, 2029
Proceeds from debt, including premium net of debt issuance costs				$ 64
PPL Electric [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 475
Stated interest rate		3.95%
Proceeds from debt, net of issuance costs		$ 466
Maturity date		Jun. 1, 2047
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2017 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Stated interest rate	3.75%						3.75%		3.75%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 1, 2027
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Maturity date	Jun. 1, 2033
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 31						$ 31		$ 31
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 3, 2019
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 35						$ 35		$ 35
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 3, 2019
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.50%
Maturity date			Oct. 1, 2033
Repurchase date of debt instruments			Apr. 1, 2019
PPL Electric Utilities Corp [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 475
Stated interest rate		3.95%
Proceeds from debt, net of issuance costs		$ 466
Maturity date		Jun. 1, 2047
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2017 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Stated interest rate	3.75%						3.75%		3.75%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 1, 2027
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Maturity date	Jun. 1, 2033
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 31						$ 31		$ 31
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 3, 2019
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 35						$ 35		$ 35
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 3, 2019
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.50%
Maturity date			Oct. 1, 2033
Repurchase date of debt instruments			Apr. 1, 2019
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2017 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Stated interest rate	3.75%						3.75%		3.75%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 1, 2027
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Maturity date	Jun. 1, 2033
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 31						$ 31		$ 31
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 3, 2019
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 35						$ 35		$ 35
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 1, 2033
Repurchase date of debt instruments	Jun. 3, 2019
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.50%
Maturity date			Oct. 1, 2033
Repurchase date of debt instruments			Apr. 1, 2019
At The Market Stock Offering Program [Member]
Equity Programs [Line Items]
Stock Issued During Period, Shares, New Issues | shares							2,113	0	3,477	0
At-the-Market Stock Offering Program (Numeric) [Abstract]
Number of distribution agreements | Integer						2
Aggregate sales price of common stock based on two separate equity distribution agreements						$ 500
Average share price | $ / shares							$ 39.15	$ 0	$ 38.17	$ 0
Net proceeds from issuance of common stock							$ 82	$ 0	$ 132	$ 0

Financing Activities - Distribu

Financing Activities - Distributions (Details) - $ / shares	1 Months Ended	3 Months Ended		6 Months Ended
	May 31, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Distributions (Numeric) [Abstract]
Dividend payable date of quarterly common stock dividend	Jul. 3, 2017
Current quarterly common stock dividend (in dollars per share)	$ 0.395	$ 0.3950	$ 0.38	$ 0.79	$ 0.76
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.58

Defined Benefits (Details)

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	$ 15	$ 16	$ 32	$ 33
Interest cost	42	44	84	87
Expected return on plan assets	(58)	(58)	(115)	(114)
Amortization of: [Abstract]
Prior service cost	3	3	5	4
Actuarial loss	14	10	34	25
Net periodic defined benefit costs (credits) before special termination benefits	16	15	40	35
Special termination benefits	(1)	0	1	0
Net periodic defined benefit costs (credits)	15	15	41	35
Pension Benefits United Kingdom [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	18	18	37	36
Interest cost	44	62	87	124
Expected return on plan assets	(127)	(132)	(252)	(265)
Amortization of: [Abstract]
Prior service cost	0	0	0	0
Actuarial loss	36	36	71	73
Net periodic defined benefit costs (credits) before special termination benefits	(29)	(16)	(57)	(32)
Special termination benefits	0	0	0	0
Net periodic defined benefit costs (credits)	(29)	(16)	(57)	(32)
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Employer contributions			485
Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	2	2	4	4
Interest cost	6	7	12	13
Expected return on plan assets	(5)	(6)	(11)	(11)
Amortization of: [Abstract]
Prior service cost	(1)	0	(1)	0
Net periodic defined benefit costs (credits)	2	3	4	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	5	13	11
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	5	6	12	12
Interest cost	18	18	34	35
Expected return on plan assets	(24)	(24)	(46)	(45)
Amortization of: [Abstract]
Prior service cost	2	3	4	4
Actuarial loss	4	5	15	10
Net periodic defined benefit costs (credits)	5	8	19	16
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	2	2
Interest cost	2	3	4	5
Expected return on plan assets	(2)	(1)	(3)	(3)
Amortization of: [Abstract]
Prior service cost	0	0	0	1
Net periodic defined benefit costs (credits)	1	3	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	2	3	5	5
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	1	1
Interest cost	3	4	6	7
Expected return on plan assets	(6)	(5)	(11)	(10)
Amortization of: [Abstract]
Prior service cost	1	1	2	2
Actuarial loss	1	1	4	3
Net periodic defined benefit costs (credits)	0	2	2	3
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	$ 3	$ 5	$ 6

Commitments and Contingencies -

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details)	6 Months Ended
	Jun. 30, 2017coal-fired_unitresidentclaimmi
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	1
Additional generating units retired at the Cane Run plant | coal-fired_unit	2
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	1
Additional generating units retired at the Cane Run plant | coal-fired_unit	2
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	1
Additional generating units retired at the Cane Run plant | coal-fired_unit	2
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 Contingencies53

Commitments and Contingencies - Environmental Matters and Other (Details) $ in Millions	1 Months Ended
	Aug. 31, 2017employees	Mar. 31, 2017employees	Jun. 30, 2017USD ($)	Dec. 31, 2016USD ($)
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term		5 years
Number Of Union Employees		1,400
PPL Electric Additional Sites [Member]
Environmental Matters - Superfund and Other Remediation (Numeric) [Abstract]
Environmental site accrual | $			$ 10	$ 10
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term		5 years
Number Of Union Employees		1,400
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund and Other Remediation (Numeric) [Abstract]
Environmental site accrual | $			$ 10	$ 10
LG And E And KU Energy LLC [Member] | KU [Member] | Subsequent Event [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees	53
Collective Bargaining Expiration Date	2020-08
Kentucky Utilities Co [Member] | Subsequent Event [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees	53
Collective Bargaining Expiration Date	2020-08

Commitments and Contingencies54

Commitments and Contingencies - Guarantees and Other Assurances (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Guarantor Obligations [Line Items]
Recorded liability for all guarantees	$ 22	$ 22
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 inestimable	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	2,019
PPL Guarantee [Member] | Financial Guarantee [Member] | WPD Guarantee Of Pension And Other Obligations Of Unconsolidated Entities [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 92
PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 15
Expiration date	2,018
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 301
Term of guarantee (in years)	12
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
Maximum exposure of other indemnifications related to the purchase price of excess power	$ 100
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Minimum [Member]
Guarantor Obligations [Line Items]
Expiration date	2,021
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Maximum [Member]
Guarantor Obligations [Line Items]
Expiration date	2,023
LKE Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure inestimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 120
PPL Electric Utilities Corp [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 15
Expiration date	2,018
LG And E And KU Energy LLC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees	$ 17	$ 17
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	$ 301
Term of guarantee (in years)	12
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
Maximum exposure of other indemnifications related to the purchase price of excess power	$ 100
LG And E And KU Energy LLC [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Minimum [Member]
Guarantor Obligations [Line Items]
Expiration date	2,021
LG And E And KU Energy LLC [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Maximum [Member]
Guarantor Obligations [Line Items]
Expiration date	2,023
LG And E And KU Energy LLC [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure inestimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 120
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 inestimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 83
Kentucky Utilities Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure inestimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 37

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes receivable from affiliate	$ 270,000,000		$ 270,000,000		$ 0
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	44,000,000	$ 28,000,000	95,000,000	$ 65,000,000
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	15,000,000	16,000,000	$ 33,000,000	33,000,000
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing			2.81%
Notes receivable from affiliate	270,000,000		$ 270,000,000		0
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	159,000,000		159,000,000		163,000,000
Long-term debt to affiliate	400,000,000		400,000,000		400,000,000
Interest Expense with Affiliate	4,000,000	4,000,000	8,000,000	8,000,000
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	5,000,000	4,000,000	11,000,000	9,000,000
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	225,000,000		$ 225,000,000		$ 225,000,000
Intercompany borrowings demand note rate on outstanding borrowing			2.56%		2.12%
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					$ 400,000,000
Interest rate on ten-year note					3.50%
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	$ 400,000,000		$ 400,000,000
Interest rate on ten-year note	3.50%		3.50%
Louisville Gas And Electric Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates	$ 38,000,000	41,000,000	$ 82,000,000	88,000,000
Kentucky Utilities Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates	$ 47,000,000	$ 49,000,000	$ 91,000,000	$ 105,000,000

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents	$ 467	$ 341
Restricted cash and cash equivalents	25	26
Price risk management assets:
Foreign currency contracts	156	211
Cross-currency swaps	158	188
Total price risk management assets	314	399
Total assets	806	766
Price risk management liabilities:
Interest rate swaps	31	31
Foreign currency contracts	104	27
Total price risk management liabilities	135	58
Level 1 [Member]
Assets
Cash and cash equivalents	467	341
Restricted cash and cash equivalents	25	26
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total assets	492	367
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
Price risk management assets:
Foreign currency contracts	156	211
Cross-currency swaps	158	188
Total price risk management assets	314	399
Total assets	314	399
Price risk management liabilities:
Interest rate swaps	31	31
Foreign currency contracts	104	27
Total price risk management liabilities	135	58
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	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	59	13
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total assets	61	15
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	59	13
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total assets	61	15
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	19	13
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	21	16
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	19	13
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	21	16
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
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
LG And E And KU Energy LLC [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	7	5
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	9	8
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	7	5
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	9	8
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
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	12	7
Price risk management assets:
Total assets	12	7
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	12	7
Price risk management assets:
Total assets	12	7
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	Jun. 30, 2017	Dec. 31, 2016
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 19,068	$ 18,326
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	22,791	21,355
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,298	2,831
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,705	3,148
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	5,067	5,065
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	5,535	5,439
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,619	1,617
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,749	1,710
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	2,327	2,327
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 2,572	$ 2,514

Derivative Instruments and He58

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 27	$ 19
Cash collateral posted under master netting arrangements	2	3
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	2	3
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	$ 2	$ 3

Derivative Instruments and He59

Derivative Instruments and Hedging Activities - Risk Disclosures (Details) £ in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2017GBP (£)
Cash Flow Hedges [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 six months ended June 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net		$ 0		$ 0
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
Cash Flow Hedges [Member] | Cross Currency Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	$ 802		$ 802
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Earliest maturity date of cross-currency cash flow hedge contracts			2,017
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
Cash Flow Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	187		$ 187		£ 145
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Maturity date of interest rate swap cash flow hedge contracts			2,027
Mandatory Redemption Date of Interest Rate Swap Cash Flow Hedge			Nov. 30, 2017
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	0		$ 0
Interest Rate Cash Flow Hedge Ineffectiveness is Immaterial			For the three and six months ended June 30, 2016, PPL had an insignificant amount of hedge ineffectiveness associated with interest rate derivatives.
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			$ 21	$ 21
Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
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
Economic Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Total exposure hedged related to foreign currency contracts for anticipated earnings hedges classified as economic activity	3,700		$ 3,700		£ 2,800
Earliest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity			July 2,017
Latest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity			December 2,019
LG And E And KU Energy LLC [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
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 And Foreign Currency Risk [Line Items]
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 He60

Derivative Instruments and Hedging Activities - Fair Values (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 158	$ 188
Liability value	1	0
Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	28	32
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	28	32
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	130	156
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	130	156
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	1	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	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	156	211
Liability value	134	58
Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	41	31
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	41	31
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	115	180
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	115	180
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	65	25
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	5	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	60	21
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	69	33
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	25	27
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	44	6
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	30	31
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	5	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	5	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	25	27
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	25	27
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	30	31
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	5	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	5	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	25	27
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	$ 25	$ 27

Derivative Instruments and He61

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Cash Flow Hedges [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	$ (32)	$ (106)	$ (30)	$ (9)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	(1)	0
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)	(29)	(107)	(37)	(12)
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)	(2)	(3)	(2)	(21)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	(2)	(2)	(4)	(3)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	(1)	0
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)	(104)	(35)	9
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)	0	0
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)	(29)	(103)	(26)	(6)
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	0	4
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(114)	169	(159)	227
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	(113)	171	(156)	231
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	(1)	(3)	1	(9)
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)	(2)	(3)	(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	(1)	(3)	1	(9)
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)	(2)	(3)	(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	(1)	(3)	1	(9)
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)	$ (2)	$ (3)	$ (4)

Derivative Instruments and He62

Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$ 23
Aggregate fair value of collateral posted on these derivative instruments	2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	21
Treasury Derivatives [Member]
Assets [Abstract]
Gross	314	$ 399
Derivative instruments - eligible for offset	93	27
Cash collateral received - eligible for offset	27	19
Net	194	353
Liabilities [Abstract]
Gross	135	58
Derivative instruments - eligible for offset	93	27
Cash collateral pledged - eligible for offset	2	3
Net	40	28
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	12
Aggregate fair value of collateral posted on these derivative instruments	2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	10
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	30	31
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	2	3
Net	28	28
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	12
Aggregate fair value of collateral posted on these derivative instruments	2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	10
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	30	31
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	2	3
Net	$ 28	$ 28

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2017
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 488
Accretion		11
Effect of foreign exchange rates		2
Changes in estimated timing or cost		(73)
Obligations settled		(12)
Balance at End of Period	$ 416	$ 416
Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 433
Accretion		10
Effect of foreign exchange rates		0
Changes in estimated timing or cost		(66)
Obligations settled		(12)
Balance at End of Period	365	365
Increase (Decrease) to the asset retirement obligations due to revisions in the amounts and timing of future expected costs related to the closure of CCR impoundments	(66)	$ (66)
LG And E And KU Energy LLC [Member] | Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
LG And E And KU Energy LLC [Member] | Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 145
Accretion		4
Effect of foreign exchange rates		0
Changes in estimated timing or cost		(10)
Obligations settled		(7)
Balance at End of Period	132	132
Increase (Decrease) to the asset retirement obligations due to revisions in the amounts and timing of future expected costs related to the closure of CCR impoundments	(56)	$ (10)
Louisville Gas And Electric Co [Member] | Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
Louisville Gas And Electric Co [Member] | Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 288
Accretion		6
Effect of foreign exchange rates		0
Changes in estimated timing or cost		(56)
Obligations settled		(5)
Balance at End of Period	233	233
Increase (Decrease) to the asset retirement obligations due to revisions in the amounts and timing of future expected costs related to the closure of CCR impoundments	$ (10)	$ (56)
Kentucky Utilities Co [Member] | Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
Kentucky Utilities Co [Member] | Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years

Accumulated Other Comprehensi64

Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (3,777)	$ (3,159)	$ (3,778)	$ (2,728)
Amounts arising during the period	196	185	166	(199)
Reclassifications from accumulated other comprehensive income	58	117	89	70
Net other comprehensive income during the period	254	302	255	(129)
Balance at end of period	(3,523)	(2,857)	(3,523)	(2,857)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(1,651)	(984)	(1,627)	(520)
Amounts arising during the period	231	268	207	(196)
Reclassifications from accumulated other comprehensive income	0	0	0	0
Net other comprehensive income during the period	231	268	207	(196)
Balance at end of period	(1,420)	(716)	(1,420)	(716)
Qualifying Derivatives Unrealized Gains (Losses) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(14)	(5)	(7)	(7)
Amounts arising during the period	(24)	(85)	(30)	(5)
Reclassifications from accumulated other comprehensive income	25	85	24	7
Net other comprehensive income during the period	1	0	(6)	2
Balance at end of period	(13)	(5)	(13)	(5)
Equity Investees Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(1)	0	(1)	0
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	1	(1)	1	(1)
Net other comprehensive income during the period	1	(1)	1	(1)
Balance at end of period	0	(1)	0	(1)
Defined Benefit Plans Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(8)	(6)	(8)	(6)
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	1	1	1	1
Net other comprehensive income during the period	1	1	1	1
Balance at end of period	(7)	(5)	(7)	(5)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(2,103)	(2,164)	(2,135)	(2,195)
Amounts arising during the period	(11)	2	(11)	2
Reclassifications from accumulated other comprehensive income	31	32	63	63
Net other comprehensive income during the period	20	34	52	65
Balance at end of period	(2,083)	(2,130)	(2,083)	(2,130)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(68)	(45)	(70)	(46)
Amounts arising during the period	(11)	1	(11)	1
Reclassifications from accumulated other comprehensive income	2	1	4	2
Net other comprehensive income during the period	(9)	2	(7)	3
Balance at end of period	(77)	(43)	(77)	(43)
LG And E And KU Energy LLC [Member] | Equity Investees Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	0	0	(1)	0
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	0	(1)	1	(1)
Net other comprehensive income during the period	0	(1)	1	(1)
Balance at end of period	0	(1)	0	(1)
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)	(10)	(8)	(10)
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	1	1	1	1
Net other comprehensive income during the period	1	1	1	1
Balance at end of period	(7)	(9)	(7)	(9)
LG And E And KU Energy LLC [Member] | Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(60)	(35)	(61)	(36)
Amounts arising during the period	(11)	1	(11)	1
Reclassifications from accumulated other comprehensive income	1	1	2	2
Net other comprehensive income during the period	(10)	2	(9)	3
Balance at end of period	$ (70)	$ (33)	$ (70)	$ (33)

Accumulated Other Comprehensi65

Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	$ (112)	$ 174	$ (159)	$ 235
Interest Expense	(222)	(224)	(439)	(448)
Income Taxes	(76)	(192)	(205)	(371)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(58)	(117)	(89)	(70)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	(32)	(106)	(31)	(9)
Income Taxes	7	21	7	2
Total After-tax	(25)	(85)	(24)	(7)
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)	(5)	(3)
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	(29)	(103)	(26)	(6)
Interest Expense	(1)	(1)	0	0
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	(1)	1	(1)	1
Total Pre-tax	(1)	1	(1)	1
Income Taxes	0	0	0	0
Total After-tax	(1)	1	(1)	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	(41)	(41)	(82)	(81)
Income Taxes	9	8	18	17
Total After-tax	(32)	(33)	(64)	(64)
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)	(1)	(1)
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	$ (40)	$ (40)	$ (81)	$ (80)