LG&E & KU Energy 10-K 19 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Jan. 31, 2016	Jun. 30, 2015
Document Entity Information [Line Items]
Document Type	10-K
Document Period End Date	Dec. 31, 2015
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 Public Float			$ 19,730,584,918
Entity Common Stock, Shares Outstanding		675,190,188
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	PPL ELECTRIC UTILITIES CORP
Entity Central Index Key	317,187
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		66,368,056
LG And E And KU Energy LLC [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LG&E & KU Energy LLC
Entity Central Index Key	1,518,339
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LOUISVILLE GAS & ELECTRIC CO
Entity Central Index Key	60,549
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		21,294,223
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	KENTUCKY UTILITIES CO
Entity Central Index Key	55,387
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		37,817,878

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Revenues
Operating Revenues		$ 7,669	$ 7,852	$ 7,263
Operation
Fuel		863	965	895
Energy purchases		855	924	856
Other operation and maintenance		1,938	1,856	1,810
Depreciation		883	923	843
Taxes, other than income		299	317	298
Total Operating Expenses		4,838	4,985	4,702
Operating Income		2,831	2,867	2,561
Other Income (Expense) - net		108	105	(55)
Interest Expense		871	843	778
Income Before Income Taxes		2,068	2,129	1,728
Income Taxes		465	692	360
Income from Continuing Operations After Income Taxes		1,603	1,437	1,368
Income (Loss) from Discontinued Operations (net of income taxes)		(921)	300	(238)
Net Income		$ 682	$ 1,737	$ 1,130
Income from Continuing Operations After Income Taxes Available to PPL Common Shareowners:
Basic (in dollars per share)		$ 2.38	$ 2.19	$ 2.24
Diluted (in dollars per share)		2.37	2.16	2.12
Net Income Available to PPL Common Shareowners:
Basic (in dollars per share)		1.01	2.64	1.85
Diluted (in dollars per share)		1.01	2.61	1.76
Dividends Declared Per Share of Common Stock		$ 1.5	$ 1.49	$ 1.47
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		669,814	653,504	608,983
Diluted		672,586	665,973	663,073
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 2,124	$ 2,044	$ 1,870
Operation
Energy purchases		657	587	588
Energy purchases from affiliates		14	84	51
Other operation and maintenance		607	543	531
Depreciation		214	185	178
Taxes, other than income		94	107	103
Total Operating Expenses		1,586	1,506	1,451
Operating Income		538	538	419
Other Income (Expense) - net		8	7	6
Interest Expense		130	122	108
Income Before Income Taxes		416	423	317
Income Taxes		164	160	108
Net Income	[1]	252	263	209
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		3,115	3,168	2,976
Operation
Fuel		863	965	896
Energy purchases		184	253	217
Other operation and maintenance		837	815	778
Depreciation		382	354	334
Taxes, other than income		57	52	48
Total Operating Expenses		2,323	2,439	2,273
Operating Income		792	729	703
Other Income (Expense) - net		(8)	(9)	(7)
Interest Expense		178	167	144
Interest Expense with Affiliates		3	0	1
Income Before Income Taxes		603	553	551
Income Taxes		239	209	206
Income from Continuing Operations After Income Taxes		364	344	345
Income (Loss) from Discontinued Operations (net of income taxes)		0	0	2
Net Income		364	344	347
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		1,407	1,445	1,351
Electric revenue from affiliates		37	88	59
Operating Revenues		1,444	1,533	1,410
Operation
Fuel		329	404	367
Energy purchases		166	230	195
Energy purchases from affiliates		20	14	10
Other operation and maintenance		377	379	373
Depreciation		162	157	148
Taxes, other than income		28	25	24
Total Operating Expenses		1,082	1,209	1,117
Operating Income		362	324	293
Other Income (Expense) - net		(6)	(3)	(2)
Interest Expense		57	49	34
Income Before Income Taxes		299	272	257
Income Taxes		114	103	94
Net Income	[2]	185	169	163
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		1,708	1,723	1,625
Electric revenue from affiliates		20	14	10
Operating Revenues		1,728	1,737	1,635
Operation
Fuel		534	561	529
Energy purchases		18	23	22
Energy purchases from affiliates		37	88	59
Other operation and maintenance		435	408	382
Depreciation		220	197	186
Taxes, other than income		29	27	24
Total Operating Expenses		1,273	1,304	1,202
Operating Income		455	433	433
Other Income (Expense) - net		1	(1)	(3)
Interest Expense		82	77	70
Income Before Income Taxes		374	355	360
Income Taxes		140	135	132
Net Income	[1]	$ 234	$ 220	$ 228
[1]	Net income approximates comprehensive income.
[2]	Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net income		$ 682	$ 1,737	$ 1,130
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax		(234)	(275)	138
Available-for-sale securities, net of tax		8	35	67
Qualifying derivatives, net of tax		26	(10)	45
Defined benefit plans:
Prior service costs, net of tax		(9)	5	2
Net actuarial gain (loss), net of tax		(366)	(509)	71
Reclassifications to net income - (gains) losses, net of tax expense (benefit):
Available-for-sale securities, net of tax		(2)	(6)	(6)
Qualifying derivatives, net of tax		2	(64)	(83)
Equity investee's other comprehensive (income) loss, net of tax		1	0	0
Defined benefit plans:
Prior service costs, net of tax		0	4	6
Net actuarial loss, net of tax		146	111	135
Total other comprehensive income (loss)		(430)	(709)	375
Comprehensive income (loss)		252	1,028	1,505
PPL Electric Utilities Corp [Member]
Net income	[1]	252	263	209
LG And E And KU Energy LLC [Member]
Net income		364	344	347
Defined benefit plans:
Prior service costs, net of tax		(3)	(7)	0
Net actuarial gain (loss), net of tax		(4)	(50)	28
Reclassifications to net income - (gains) losses, net of tax expense (benefit):
Equity investee's other comprehensive (income) loss, net of tax		0	(1)	0
Defined benefit plans:
Prior service costs, net of tax		1	1	0
Net actuarial loss, net of tax		5	(1)	0
Total other comprehensive income (loss)		(1)	(58)	28
Comprehensive income (loss)		363	286	375
Louisville Gas And Electric Co [Member]
Net income	[2]	185	169	163
Kentucky Utilities Co [Member]
Net income	[1]	$ 234	220	$ 228
Defined benefit plans:
Total other comprehensive income (loss)			$ (1)
[1]	Net income approximates comprehensive income.
[2]	Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF COM4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Tax effect of foreign currency translation adjustments arising during the period	$ 1	$ (8)	$ 4
Tax effect of available-for-sale securities arising during the period	(9)	(39)	(72)
Tax effect of qualifying derivatives arising during the period	0	23	(41)
Tax effect of defined benefit plans - prior service costs arising during period	6	(4)	(1)
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	67	225	(73)
Tax effect of available-for-sale securities reclassified to net income	2	7	4
Tax effect of qualifying derivatives reclassified to net income	(15)	23	80
Tax effect of equity investees' other comprehensive (income) loss reclassified to net income	0	0	0
Tax effect of prior service costs reclassified to net income	0	(3)	(4)
Tax effect of net actuarial loss reclassified to net income	(46)	(34)	(49)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - prior service costs arising during period	2	4	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	2	32	(18)
Tax effect of equity investees' other comprehensive (income) loss reclassified to net income	0	0	0
Tax effect of prior service costs reclassified to net income	(1)	0	0
Tax effect of net actuarial loss reclassified to net income	$ (3)	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash Flows from Operating Activities
Net income		$ 682	$ 1,737	$ 1,130
Income (Loss) from Discontinued Operations (net of income taxes)		(921)	300	(238)
Income from continuing operations (net of income taxes)		1,603	1,437	1,368
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation		883	923	843
Amortization		59	65	66
Defined benefit plans - expense		56	48	125
Deferred income taxes and investment tax credits		428	666	387
Unrealized (gains) losses on derivatives, and other hedging activities		(77)	(187)	56
Adjustment to WPD line loss accrual		0	65	45
Other		17	66	0
Change in current assets and current liabilities
Accounts receivable		47	(123)	(211)
Accounts payable		(116)	40	127
Unbilled revenues		54	22	(56)
Prepayments		(23)	87	39
Taxes payable		(175)	161	51
Uncertain tax positions		(17)	0	(112)
Other		99	23	(66)
Other operating activities
Defined benefit plans - funding		(499)	(384)	(450)
Settlement of interest rate swaps		0	0	104
Settlement of interest rate swaps		(101)	0	0
Other assets		(19)	9	11
Other liabilities		53	23	120
Net cash provided by (used in) operating activities		2,272	2,941	2,447
Net cash provided by (used in) operating activities - discontinued operations		343	462	409
Net cash provided by (used in) operating activities		2,615	3,403	2,856
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(3,533)	(3,674)	(3,629)
Expenditures for intangible assets		(37)	(49)	(53)
Purchases of other investments		0	(120)	0
Proceeds from the sale of other investments		136	0	0
Net (increase) decrease in restricted cash and cash equivalents		8	19	2
Other investing activities		(13)	(2)	16
Net cash provided by (used in) investing activities		(3,439)	(3,826)	(3,664)
Net cash provided by (used in) investing activities - discontinued operations		(149)	497	(631)
Net cash provided by (used in) investing activities		(3,588)	(3,329)	(4,295)
Cash Flows from Financing Activities
Issuance of long-term debt		2,236	296	2,038
Retirement of long-term debt		(1,000)	(237)	0
Repurchase of common stock		0	0	(74)
Issuance of common stock		203	1,074	1,411
Payment of common stock dividends		(1,004)	(967)	(878)
Contract adjustment payments on Equity Units		0	(22)	(82)
Net increase (decrease) in short-term debt		94	147	405
Other financing activities		(47)	(29)	(67)
Net cash provided by (used in) financing activities		482	262	2,753
Net cash provided by (used in) financing activities - discontinued operations		(546)	(846)	47
Net cash distributions to parent from discontinued operations		132	1,167	(1,169)
Net cash provided by (used in) financing activities		68	583	1,631
Effect of Exchange Rates on Cash and Cash Equivalents		(10)	(8)	8
Net (Increase) Decrease in Cash and Cash Equivalents included in Discontinued Operations		(352)	113	(175)
Net Increase (Decrease) in Cash and Cash Equivalents		(563)	536	375
Cash and Cash Equivalents at Beginning of Period		1,399	863	488
Cash and Cash Equivalents at End of Period		836	1,399	863
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		822	959	916
Income taxes - net		179	190	128
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income	[1]	252	263	209
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation		214	185	178
Amortization		26	19	19
Defined benefit plans - expense		16	15	21
Deferred income taxes and investment tax credits		220	87	127
Other		(12)	(23)	(9)
Change in current assets and current liabilities
Accounts receivable		50	(64)	(29)
Accounts payable		(107)	30	12
Unbilled revenues		22	3	(6)
Prepayments		(1)	1	36
Taxes payable		(108)	75	49
Regulatory assets and liabilities		35	5	19
Other		21	10	(28)
Other operating activities
Defined benefit plans - funding		(33)	(23)	(93)
Other assets		(10)	19	8
Other liabilities		17	11	10
Net cash provided by (used in) operating activities		602	613	523
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,097)	(931)	(903)
Expenditures for intangible assets		(10)	(26)	(39)
Net (increase) decrease in notes receivable from affiliates		0	150	(150)
Other investing activities		(1)	16	12
Net cash provided by (used in) investing activities		(1,108)	(791)	(1,080)
Cash Flows from Financing Activities
Issuance of long-term debt		348	296	348
Retirement of long-term debt		(100)	(10)	0
Contributions from parent		275	263	205
Payment of common stock dividends to parent		(181)	(158)	(127)
Net increase (decrease) in short-term debt		0	(20)	20
Other financing activities		(3)	(4)	(4)
Net cash provided by (used in) financing activities		339	367	442
Net Increase (Decrease) in Cash and Cash Equivalents		(167)	189	(115)
Cash and Cash Equivalents at Beginning of Period		214	25	140
Cash and Cash Equivalents at End of Period		47	214	25
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		117	110	87
Income taxes - net		38	40	(45)
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net income		364	344	347
Income (Loss) from Discontinued Operations (net of income taxes)		0	0	2
Income from continuing operations (net of income taxes)		364	344	345
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation		382	354	334
Amortization		27	25	22
Defined benefit plans - expense		38	25	48
Deferred income taxes and investment tax credits		236	449	254
Other		2	16	5
Change in current assets and current liabilities
Accounts receivable		24	(20)	(91)
Accounts payable		(58)	12	40
Accounts payable to affiliates		(2)	(1)	1
Unbilled revenues		20	13	(24)
Fuel, materials and supplies		6	(32)	(1)
Income tax receivable		135	(136)	1
Taxes payable		10	(3)	13
Accrued interest		9	0	2
Other		23	(1)	20
Other operating activities
Defined benefit plans - funding		(70)	(45)	(168)
Settlement of interest rate swaps		0	0	86
Settlement of interest rate swaps		(88)	0	0
Other assets		(7)	(7)	9
Other liabilities		12	6	22
Net cash provided by (used in) operating activities		1,063	999	920
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,210)	(1,262)	(1,434)
Net (increase) decrease in notes receivable from affiliates		0	70	(70)
Other investing activities		7	1	2
Net cash provided by (used in) investing activities		(1,203)	(1,191)	(1,502)
Cash Flows from Financing Activities
Issuance of long-term debt		1,050	0	496
Issuance of long-term debt with affiliates		400	0	0
Retirement of long-term debt		900	0	0
Contributions from member		125	248	243
Distributions to member		(219)	(436)	(254)
Debt issuance and credit facility costs		(10)	(5)	(6)
Net increase (decrease) in notes payable to affiliates		13	41	(25)
Net increase (decrease) in short-term debt		(310)	330	120
Net cash provided by (used in) financing activities		149	178	574
Net Increase (Decrease) in Cash and Cash Equivalents		9	(14)	(8)
Cash and Cash Equivalents at Beginning of Period		21	35	43
Cash and Cash Equivalents at End of Period		30	21	35
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		163	157	137
Income taxes - net		(139)	(75)	(67)
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income	[2]	185	169	163
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation		162	157	148
Amortization		11	12	6
Defined benefit plans - expense		12	9	18
Deferred income taxes and investment tax credits		126	118	26
Other		8	2	9
Change in current assets and current liabilities
Accounts receivable		19	(12)	(37)
Accounts receivable from affiliates		(11)	23	(14)
Accounts payable		(29)	25	16
Accounts payable to affiliates		5	(4)	1
Unbilled revenues		9	9	(13)
Fuel, materials and supplies		3	(8)	(12)
Income tax receivable		70	(74)	0
Taxes payable		1	8	9
Accrued interest		5	0	1
Other		17	0	7
Other operating activities
Defined benefit plans - funding		(26)	(13)	(48)
Settlement of interest rate swaps		0	0	43
Settlement of interest rate swaps		(44)	0	0
Other assets		11	(2)	9
Other liabilities		(2)	(2)	6
Net cash provided by (used in) operating activities		554	371	366
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(689)	(656)	(577)
Net cash provided by (used in) investing activities		(689)	(656)	(577)
Cash Flows from Financing Activities
Issuance of long-term debt		550	0	248
Retirement of long-term debt		250	0	0
Contributions from parent		90	157	86
Payment of common stock dividends to parent		(119)	(112)	(99)
Debt issuance and credit facility costs		(5)	(2)	(3)
Net increase (decrease) in short-term debt		(122)	244	(35)
Net cash provided by (used in) financing activities		144	287	197
Net Increase (Decrease) in Cash and Cash Equivalents		9	2	(14)
Cash and Cash Equivalents at Beginning of Period		10	8	22
Cash and Cash Equivalents at End of Period		19	10	8
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		48	46	36
Income taxes - net		(81)	65	51
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income	[1]	234	220	228
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation		220	197	186
Amortization		13	11	14
Defined benefit plans - expense		10	5	18
Deferred income taxes and investment tax credits		160	224	69
Other		(5)	13	(3)
Change in current assets and current liabilities
Accounts receivable		5	(9)	(44)
Accounts receivable from affiliates		1	0	(7)
Accounts payable		(32)	(10)	23
Accounts payable to affiliates		(10)	22	(8)
Unbilled revenues		11	4	(11)
Fuel, materials and supplies		3	(25)	10
Income tax receivable		59	(60)	0
Taxes payable		6	(19)	7
Accrued interest		5	0	1
Other		4	(5)	9
Other operating activities
Defined benefit plans - funding		(21)	(5)	(65)
Settlement of interest rate swaps		0	0	43
Settlement of interest rate swaps		(44)	0	0
Other assets		(11)	(4)	1
Other liabilities		2	7	10
Net cash provided by (used in) operating activities		608	566	495
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(519)	(604)	(855)
Other investing activities		7	1	2
Net cash provided by (used in) investing activities		(512)	(603)	(853)
Cash Flows from Financing Activities
Issuance of long-term debt		500	0	248
Retirement of long-term debt		250	0	0
Contributions from parent		0	91	157
Payment of common stock dividends to parent		(153)	(148)	(124)
Debt issuance and credit facility costs		(5)	(2)	(3)
Net increase (decrease) in short-term debt		(188)	86	80
Net cash provided by (used in) financing activities		(96)	27	358
Net Increase (Decrease) in Cash and Cash Equivalents		0	(10)	0
Cash and Cash Equivalents at Beginning of Period		11	21	21
Cash and Cash Equivalents at End of Period		11	11	21
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		75	73	61
Income taxes - net		$ (84)	$ 0	$ 47
[1]	Net income approximates comprehensive income.
[2]	Net income equals comprehensive income.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Current Assets
Cash and cash equivalents		$ 836	$ 1,399
Short-term investments		0	120
Accounts receivable (less reserve:)
Customer		673	737
Other		59	71
Unbilled revenues		453	517
Fuel, materials and supplies		357	381
Prepayments		66	75
Price risk management assets		139	79
Regulatory assets	[1]	48	37
Other current assets		63	55
Current assets of discontinued operations		0	2,592
Total Current Assets		2,646	6,026
Property, Plant and Equipment
Regulated utility plant		34,399	30,568
Less: accumulated depreciation - regulated utility plant		5,683	5,361
Non-regulated property, plant and equipment		516	592
Less: accumulated depreciation - non-regulated property, plant and equipment		165	162
Non-regulated property, plant and equipment, net		351	430
Non-regulated property, plant and equipment
Construction work in progress		1,315	2,532
Property, Plant and Equipment, net		30,382	28,169
Other Noncurrent Assets
Regulatory assets		1,733	1,562
Goodwill		3,550	3,667
Other intangibles		679	668
Other noncurrent assets		311	203
Noncurrent assets of discontinued operations		0	8,311
Total Other Noncurrent Assets		6,273	14,411
Total Assets		39,301	48,606
Current Liabilities
Short-term debt		916	836
Long-term debt due within one year		485	1,000
Accounts payable		812	995
Taxes		85	263
Interest		303	298
Dividends		255	249
Regulatory liabilities		145	91
Customer deposits		326	304
Other current liabilities		549	632
Current liabilities of discontinued operations		0	2,771
Total Current Liabilities		3,876	7,439
Long-term Debt		18,563	17,054
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,440	3,102
Investment tax credits		128	132
Accrued pension obligations		1,405	1,457
Asset retirement obligations		536	324
Regulatory liabilities		945	992
Other deferred credits and noncurrent liabilities		489	525
Noncurrent liabilities of discontinued operations		0	3,953
Total Deferred Credits and Other Noncurrent Liabilities		$ 6,943	$ 10,485
Commitments and Contingent Liabilities
Equity
Common stock	[2]	$ 7	$ 7
Additional paid-in capital		9,687	9,433
Earnings reinvested		2,953	6,462
Accumulated other comprehensive income (loss)		(2,728)	(2,274)
Total Stockholders' Equity		9,919	13,628
Total Liabilities and Equity		39,301	48,606
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		47	214
Accounts receivable (less reserve:)
Customer		286	312
Other		10	44
Unbilled revenues		91	113
Fuel, materials and supplies		34	43
Prepayments		66	10
Regulatory assets		13	12
Other current assets		8	13
Total Current Assets		555	761
Property, Plant and Equipment
Regulated utility plant		8,734	7,589
Less: accumulated depreciation - regulated utility plant		2,573	2,517
Non-regulated property, plant and equipment
Construction work in progress		530	738
Property, Plant and Equipment, net		6,691	5,810
Other Noncurrent Assets
Regulatory assets		1,006	897
Other intangibles		244	235
Other noncurrent assets		15	3
Total Other Noncurrent Assets		1,265	1,135
Total Assets		8,511	7,706
Current Liabilities
Long-term debt due within one year		0	100
Accounts payable		288	325
Accounts payable to affiliates		35	70
Taxes		24	85
Interest		37	34
Regulatory liabilities		113	76
Customer deposits		31	34
Other current liabilities		77	69
Total Current Liabilities		605	793
Long-term Debt		2,828	2,481
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,663	1,425
Accrued pension obligations		183	212
Regulatory liabilities		22	18
Other deferred credits and noncurrent liabilities		91	60
Total Deferred Credits and Other Noncurrent Liabilities		$ 1,959	$ 1,715
Commitments and Contingent Liabilities
Equity
Common stock	[3]	$ 364	$ 364
Additional paid-in capital		1,934	1,603
Earnings reinvested		821	750
Total Stockholders' Equity		3,119	2,717
Total Liabilities and Equity		8,511	7,706
LG And E And KU Energy LLC [Member]
Current Assets
Cash and cash equivalents		30	21
Accounts receivable (less reserve:)
Customer		209	231
Other		16	18
Unbilled revenues		147	167
Fuel, materials and supplies		298	311
Prepayments		23	28
Income taxes receivable		1	136
Regulatory assets		35	25
Other current assets		6	3
Total Current Assets		765	940
Property, Plant and Equipment
Regulated utility plant		11,906	10,014
Less: accumulated depreciation - regulated utility plant		1,163	1,069
Non-regulated property, plant and equipment
Construction work in progress		660	1,559
Property, Plant and Equipment, net		11,403	10,504
Other Noncurrent Assets
Regulatory assets		727	665
Goodwill		996	996
Other intangibles		123	174
Other noncurrent assets		76	77
Total Other Noncurrent Assets		1,922	1,912
Total Assets		14,090	13,356
Current Liabilities
Short-term debt		265	575
Long-term debt due within one year		25	900
Notes payable with affiliates		54	41
Accounts payable		266	399
Accounts payable to affiliates		5	2
Taxes		46	36
Interest		32	23
Price risk management liabilities		5	5
Price risk management liabilities to affiliates		0	66
Regulatory liabilities		32	15
Customer deposits		52	52
Other current liabilities		185	131
Total Current Liabilities		967	2,245
Long-term debt		4,663	3,643
Long-term debt to affiliate		400	0
Long-term Debt		5,063	3,643
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,463	1,225
Investment tax credits		128	131
Price risk management liabilities		42	43
Accrued pension obligations		296	305
Asset retirement obligations		485	274
Regulatory liabilities		923	974
Other deferred credits and noncurrent liabilities		206	268
Total Deferred Credits and Other Noncurrent Liabilities		$ 3,543	$ 3,220
Commitments and Contingent Liabilities
Equity
Member's Equity		$ 4,517	$ 4,248
Total Liabilities and Equity		14,090	13,356
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		19	10
Accounts receivable (less reserve:)
Customer		92	107
Other		7	11
Accounts receivable from affiliates		12	23
Unbilled revenues		67	76
Fuel, materials and supplies		151	162
Prepayments		5	8
Income taxes receivable		4	74
Regulatory assets		16	21
Other current assets		2	1
Total Current Assets		375	493
Property, Plant and Equipment
Regulated utility plant		4,804	4,031
Less: accumulated depreciation - regulated utility plant		404	456
Non-regulated property, plant and equipment
Construction work in progress		390	676
Property, Plant and Equipment, net		4,790	4,251
Other Noncurrent Assets
Regulatory assets		424	397
Goodwill		389	389
Other intangibles		73	97
Other noncurrent assets		17	27
Total Other Noncurrent Assets		903	910
Total Assets		6,068	5,654
Current Liabilities
Short-term debt		142	264
Long-term debt due within one year		25	250
Accounts payable		157	240
Accounts payable to affiliates		25	20
Taxes		20	19
Interest		11	6
Price risk management liabilities		5	5
Price risk management liabilities to affiliates		0	33
Regulatory liabilities		13	10
Customer deposits		26	25
Other current liabilities		64	42
Total Current Liabilities		488	914
Long-term Debt		1,617	1,095
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		829	700
Investment tax credits		35	36
Price risk management liabilities		42	43
Accrued pension obligations		56	57
Asset retirement obligations		149	66
Regulatory liabilities		431	458
Other deferred credits and noncurrent liabilities		91	111
Total Deferred Credits and Other Noncurrent Liabilities		$ 1,633	$ 1,471
Commitments and Contingent Liabilities
Equity
Common stock	[4]	$ 424	$ 424
Additional paid-in capital		1,611	1,521
Earnings reinvested		295	229
Total Stockholders' Equity		2,330	2,174
Total Liabilities and Equity		6,068	5,654
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		11	11
Accounts receivable (less reserve:)
Customer		117	124
Affiliate		1	0
Other		8	6
Unbilled revenues		80	91
Fuel, materials and supplies		147	149
Prepayments		8	10
Income taxes receivable		1	60
Regulatory assets		19	4
Other current assets		4	2
Total Current Assets		396	457
Property, Plant and Equipment
Regulated utility plant		7,099	5,977
Less: accumulated depreciation - regulated utility plant		759	611
Non-regulated property, plant and equipment
Construction work in progress		267	880
Property, Plant and Equipment, net		6,607	6,246
Other Noncurrent Assets
Regulatory assets		303	268
Goodwill		607	607
Other intangibles		50	77
Other noncurrent assets		48	46
Total Other Noncurrent Assets		1,008	998
Total Assets		8,011	7,701
Current Liabilities
Short-term debt		48	236
Long-term debt due within one year		0	250
Accounts payable		88	141
Accounts payable to affiliates		39	47
Taxes		20	14
Interest		16	11
Price risk management liabilities to affiliates		0	33
Regulatory liabilities		19	5
Customer deposits		26	27
Other current liabilities		69	41
Total Current Liabilities		325	805
Long-term Debt		2,326	1,829
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,046	882
Investment tax credits		93	95
Accrued pension obligations		46	59
Asset retirement obligations		336	208
Regulatory liabilities		492	516
Other deferred credits and noncurrent liabilities		60	101
Total Deferred Credits and Other Noncurrent Liabilities		$ 2,073	$ 1,861
Commitments and Contingent Liabilities
Equity
Common stock	[5]	$ 308	$ 308
Additional paid-in capital		2,596	2,596
Earnings reinvested		383	302
Total Stockholders' Equity		3,287	3,206
Total Liabilities and Equity		$ 8,011	$ 7,701
[1]	For PPL, these amounts are included in "Other current assets" on the Balance Sheets.
[2]	780,000 shares authorized; 673,857 and 665,849 shares issued and outstanding at December 31, 2015 and 2014 .
[3]	170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2015 and 2014 .
[4]	75 , 000 shares authorized; 21 , 294 shares issued and outstanding at December 31, 2015 and December 31, 2014 .
[5]	80 , 000 shares authorized; 37 , 818 shares issued and outstanding at December 31, 2015 and December 31, 2014 .

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 41	$ 44
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	780,000	780,000
Common stock shares issued	673,857	665,849
Common stock shares outstanding	673,857	665,849
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 16	$ 17
Equity
Common stock no par value
Common stock shares authorized	170,000	170,000
Common stock shares issued	66,368	66,368
Common stock shares outstanding	66,368	66,368
LG And E And KU Energy LLC [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 23	$ 25
Louisville Gas And Electric Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 1	$ 2
Equity
Common stock no par value
Common stock shares authorized	75,000	75,000
Common stock shares issued	21,294	21,294
Common stock shares outstanding	21,294	21,294
Kentucky Utilities Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 2	$ 2
Equity
Common stock no par value
Common stock shares authorized	80,000	80,000
Common stock shares issued	37,818	37,818
Common stock shares outstanding	37,818	37,818

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) shares in Thousands, $ in Millions		Total	Common Stock		Additional Paid-in Capital	Earnings Reinvested	Accumulated Other Comprehensive Loss	Non-controlling Interests	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member]Common Stock		PPL Electric Utilities Corp [Member]Additional Paid-in Capital		PPL Electric Utilities Corp [Member]Earnings Reinvested	LG And E And KU Energy LLC [Member]	Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member]Common Stock		Louisville Gas And Electric Co [Member]Additional Paid-in Capital	Louisville Gas And Electric Co [Member]Earnings Reinvested	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member]Common Stock		Kentucky Utilities Co [Member]Additional Paid-in Capital	Kentucky Utilities Co [Member]Earnings Reinvested	Kentucky Utilities Co [Member]Accumulated Other Comprehensive Loss
Balance at beginning of period - shares at Dec. 31, 2012			581,944	[1]							66,368	[2]							21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2012																$ 3,786
Balance at beginning of period at Dec. 31, 2012		$ 10,498	$ 6		$ 6,936	$ 5,478	$ (1,940)	$ 18	$ 2,062		$ 364		$ 1,135		$ 563		$ 1,810		$ 424		$ 1,278	$ 108	$ 2,783		$ 308		$ 2,348	$ 126	$ 1
Common stock shares issued	[1]		50,807
Common stock issued		1,437			1,437
Common stock shares repurchased			(2,430)
Common stock repurchased		74			(74)
Cash settlement of equity forward agreements		(13)			(13)
Stock-based compensation		30			30
Net income		1,130				1,130			209	[5]					209	347	163	[6]				163	228	[5]				228
Capital contributions from parent									205				205				86				86		157				157
Dividends, dividend equivalents, redemptions and distributions		(917)				(899)		(18)
Cash dividends declared on common stock									127						127		(99)					(99)	(124)					(124)
Contributions from member																243
Distributions to member																(254)
Other comprehensive income (loss)		375					375									28
Balance at end of period - shares at Dec. 31, 2013			630,321	[1]							66,368	[2]							21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2013																4,150
Balance at end of period at Dec. 31, 2013		12,466	$ 6		8,316	5,709	(1,565)	$ 0	2,349		$ 364		1,340		645		1,960		$ 424		1,364	172	3,044		$ 308		2,505	230	1
Common stock shares issued	[1]		35,528
Common stock issued		1,090	$ 1		1,089
Stock-based compensation		28			28
Net income		1,737				1,737			263	[5]					263	344	169	[6]				169	220	[5]				220
Capital contributions from parent									263				263				157				157		91				91
Dividends, dividend equivalents, redemptions and distributions		(984)				(984)
Cash dividends declared on common stock									$ 158						158		$ (112)					(112)	(148)					(148)
Contributions from member																248
Distributions to member																(436)
Other comprehensive income (loss)		$ (709)					(709)									(58)							$ (1)						(1)
Balance at end of period - shares at Dec. 31, 2014		665,849	665,849	[1]					66,368		66,368	[2]					21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2014																4,248
Balance at end of period at Dec. 31, 2014		$ 13,628	$ 7		9,433	6,462	(2,274)		$ 2,717		$ 364		1,603		750		$ 2,174		$ 424		1,521	229	$ 3,206		$ 308		2,596	302	0
Common stock shares issued			8,008
Common stock issued		249			249
Stock-based compensation		5			5
Net income		682				682			252	[5]					252	364	185	[6]				185	234	[5]				234
Capital contributions from parent									331	[7]			331	[7]			90				90
Dividends, dividend equivalents, redemptions and distributions		(1,010)				(1,010)
Cash dividends declared on common stock																	$ (119)					(119)	$ (153)					(153)
Dividends declared on common stock									$ 181						181
Contributions from member																125
Distributions to member																(219)
Distribution of PPL Energy Supply		(3,205)				(3,181)	(24)
Other comprehensive income (loss)		$ (430)					(430)									(1)
Balance at end of period - shares at Dec. 31, 2015		673,857	673,857	[1]					66,368		66,368	[2]					21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2015																$ 4,517
Balance at end 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
[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 approximates comprehensive income.
[6]	Net income equals comprehensive income.
[7]	Includes non-cash contributions of $ 56 million . See Note 11 for additional information.

CONSOLIDATED STATEMENTS OF EQU9

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014	Dec. 31, 2013
Vote per share of PPL's common stock	1	1	1
PPL Electric Utilities Corp [Member]
Non-cash contributions related to remeasurement and separation of benefit plans	$ 56

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Summary of Significant Accounting Policies [Abstract]
Summary of Significant Accounting Policies	1. Summary of Significant Accounting Policies (All Registrants) General Capitalized terms and abbreviations appearing in the combined notes to financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above or within the applicable disclosure . Within combined disclosures, amounts are disclosed for any Registrant when significant. Business and Consolidation (PPL) PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the distribution of electricity in the U.K.; 2) the g eneration, transmission , distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 3) the transmission , distribution and sale of electricity in Pennsylvania . Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global , LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. WPD, a subsidiary of PPL Global, through indirect wholly owned subsidiaries operates distribution networks providing electricit y service in the U.K. WPD serves end-users in South Wales and southwest and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands) and WPD (West Midlands). PPL consolidates WPD on a one-month lag. Mater ial events, such as debt issuances that occur in the lag period, are recognized in the current period financial statements. Events that are significant but not material are disclosed . (PPL and PPL Electric) PPL Electric is a cost-based rate-regulated u tility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail cus tomers in that territory as a PLR. (PPL , LKE, LG&E and KU ) LKE is a utility holding company with cost-based rate- regulated utility operations through its subsidiaries, LG&E and KU . LG&E and KU are engaged in the generation, transmission, distribution and sale of electric ity . LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia (under the Old Dominion Power name) and in Tennessee under the KU name. (PPL ) "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statements of Income includes the activities of PPL Energy Supply, substantially representing PPL's fo rmer Supply segment, which was spun off and distributed to PPL shareowners on June 1, 2015. PPL Energy Supply's assets and liabilities have been reclassified on PPL's Balance Sheet at December 31, 2014 to "Current assets of discontinued operations", "Nonc urrent assets of discontinued operations", "Current liabilities of discontinued operations" and "Noncurrent liabilities of discontinued operations". These assets and liabilities were distributed and removed from PPL's Balance Sheet in the second quarter o f 2015. In addition, the Statements of Cash Flows separately report the cash flows of the discontinued operations. See Note 8 for additional information. ( All Registrants ) The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Var iable Interest Entities ( VIEs ) . The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE, and thus are the primary beneficiary of the entity. T he Registrants are not the primary beneficiary in any VIEs. Inv est ments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. All significant intercompany transactions have been eliminated. The financial statements of PPL, LKE, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 12 for additional information. Regulation (PPL) WPD operates in an incentive-based regulatory structure under distribution licenses granted by Ofgem . Electricity distribution revenues are set by Ofgem for a given time period through price control reviews that are not directly based on cost recovery. The price control formula that governs WPD's allowed revenue is designed to provide economic incentives to minimize operating, capital and financing costs . As a result, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. (All Registrants) PPL Electric, LG&E and KU are cost-based rate-regulated utiliti es for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a futu re test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or ev ents where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incu rred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decis ions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters. Accounting Records (All Registrants) The system of accounts for domestic regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions. ( All Registrants ) Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Loss Accruals Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of the uncertain future events and (2) the amount of the loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other e vents. L oss accruals for environmental remediation are discounted when appropriate. T he accrual of contingencies that might result in gains is not recorded , unless re alization is assured. Changes in Classification The classification of certain amounts in the 2014 and 2013 financial statements have been changed to conform to the current presentation. These reclassifications did not affect the Registrants' net income or equity. Earnings Per Share ( PPL ) EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-based payment awards that provide recipients a non-forfeitable right to dividends or dividend equivalents are considered participating securities. Price Risk Management ( All Registrants ) I nterest rate contracts are used to hedge exposure to change in the fair value of debt instruments and to hedge exposure s to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. F oreign currency exchange contracts are used to hedge foreign currency exposures , primarily associated with PPL's investments in U.K. subsidiaries . Similar derivatives may receive different acc ounting treatment, depending on management’s intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved that would facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. The portion of derivative positions that deliver within a year are included in "Current Assets" and "Current Liabilities," while the portion of derivative positions that deliver beyond a year are recorded in "Other Noncurrent Assets" and "Deferred Credits and Other Noncurrent Liabilities." See Note 17 to the Financi al Statements for additional information. (PPL) Processes exist that allow for subsequent review and validation of the contract information as it relates to interest rate and foreign currency derivatives. See Note 17 for more information. The acc ounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limit ed to :  Transactions to lock in an interest rate prior to a debt issuance can be d esignated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring.  Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges.  Transactions entered into to hedge fluctuations in the fair value of existing debt can be d esignated as fair value hedges.  Transactions entered into to hedge the value of a net investment of foreign operations can be designated as net investment hedges.  Derivative transactions that do not qualify for cash flow or net investment hedge t reatment are marked to fair value through earnings. These transactions generally include foreign currency forwar ds and options to hedge GBP earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP . As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates.  Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are includ ed in customer rates. (All Registrants) Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. ( PPL and PPL Electric ) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative . However, NPNS has been elected for the se contracts. See Notes 16 and 17 for additional information on derivatives . Revenue Operating Revenue s (PPL) For the years ended December 31, the Statements of Income "Operating Revenues " line item contains revenue from the following: 2015 2014 2013 Domestic electric and gas revenues (a) $ 5,239 $ 5,209 $ 4,842 U.K. operating revenues (b) 2,410 2,621 2,403 Domestic - other 20 22 18 Total $ 7,669 $ 7,852 $ 7,263 (a) Represents revenues from cost-based rate-regulated generation, transmission and/or distribution in Pennsylvania, Kentucky, Virginia and Tennessee, includ ing regulated wholesale revenue. (b) Primarily represents regulated electricity distribution revenues from the operation of WPD's distribution networks. Revenue Recognition (All Registrants ) Operating revenues are primarily recorded based on energy deliveries through the end of the calendar month. Unbilled retail revenues result because customers' meters are read and bills are rendered throughout the month, rather than all meters being read and bills rendered at the end of the month. For LKE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh by the estimated average cents per kWh . For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled kWh by the estimated average cents per kWh. An y difference between estimated and actual revenues is adjusted the following month. (PPL) WPD is currently operating under RIIO - ED1, which commenced on April 1, 2015. Ofgem has adopted a price control mechanism that establishes the amount of base dema nd revenue WPD can earn during the price control period, subject to certain true-ups, and provides for an increase or reduction in revenues based on incentives or penalties for exceeding or underperforming relative to pre-established targets. WPD’s allowe d revenue primarily includes base demand revenue, incentive adjustments, adjustments for over or under-recovery and adjustments related to the DPCR4 line loss close out. As the regulatory model is incentive based rather than a cost recovery model, WPD i s not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. Therefore, the accounting treatment of adjustments to base demand revenue and/or allowed revenue is evaluated based on revenue recognition and contingency gu idance. Unlike prior price control reviews, base demand revenue under RIIO – ED1 will be adjusted during the price control period. The most significant of those adjustments are: Inflation True-Up – The base demand revenue for the RIIO-ED1 period was s et in 2012/13 prices. Therefore an inflation factor as determined by forecasted RPI, provided by HM Treasury, is applied to base demand revenue. Forecasted RPI is trued up to actuals and affects future base demand revenue two regulatory years later. Thi s revenue change is called the "TRU" adjustment. The projected TRU for the 2015/16 regulatory year is a $45 million reduction to revenue and will reduce base demand revenue in calendar years 2017 and 2018 by $30 million and $15 million, respectively. Annual Iteration Process - The RIIO-ED1 price control period also includes an Annual Iteration Process (AIP). This will allow future base demand revenues agreed with the regulator as part of the price control review to be updated during the price control period for financial adjustments including tax, pensions and cost of debt, legacy price control adjustments from preceding price control periods and adjustments relating to actual and allowed total expenditure together with the Totex Incentive Mechanism (T IM). Under the TIM, WPD's DNOs are able to retain 70% of any amounts not spent against the RIIO-ED1 plan and bear 70% of any over-spends. The AIP calculates an incremental change to base demand revenue, known as the "MOD" adjustment. The MOD provided by Ofgem in November 2016 will include the TIM for the 2015/16 regulatory year as well as the cost of debt calculation based on the 10-year trailing average to October 2016. This projected MOD of $11 million will reduce base demand revenue for calendar years 2017 and 2018 by $5 million and $6 million, respectively. As both MOD and TRU are changes to future base demand revenues as determined by Ofgem , under applicable GAAP, liabilities for these adjustments have not been recorded. In addition to base deman d revenue, certain other items are added or subtracted to arrive at allowed revenue. The most significant of these are: Incentives - Ofgem has established incentive mechanisms to provide significant opportunities to enhance overall returns by improving network efficiency, reliability and customer service. Based on applicable GAAP, incentive revenues are not recorded as assets and are includ ed in revenues when they are billed to customers. DPCR4 Line Loss Adjustment - For regulatory years 2015/16 through 2018/19 allowed revenue will also be reduced to reflect Ofgem's final decision on the DPCR4 line loss incentives and penalties mechanism. WPD has a liability recorded related to this future revenue reduction and, therefore, this will not impact future earnings. See Note 6 to the Financial Statements for additional information. Correction Factor - During the price control period, WPD's revenue is decoupled from volume and WPD sets its tariffs to recover allowed revenue. However, in any fiscal period, WPD's revenue could be negatively affected if its tariffs and the volume delivered do not fully recover the allowed revenue for a particul ar period. Conversely, WPD could also over-recover revenue. Over and under-recoveries are subtracted from or added to allowed revenue in future years, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising from 2014/15 onwards and refunded/recovered under RIIO-ED1 will be refunded/recovered on a two year lag (previously one year). Therefore the 2014/15 over/under-recovery adjustment will occur in 2016/17. In 2016/17 under this mechanism, WPD will recover the £5 per res idential network customer reduction given through reduced tariffs in 2014/15 (approximately $56 million) as that amount is currently considered an under-recovery. Under applicable GAAP, WPD does not record a receivable for under-recoveries, but does reco rd a liability for over-recoveries. K-factor is measured as of the end of the regulatory year, March 31. While WPD estimates over-recoveries and records a liability when it is probable that there will be an over-recovered position at the end of the regul atory-year, weather-related volume changes and other factors such as sales mix can affect the over or under-recovery between the end of PPL's calendar year and the end of the regulatory year. . Accounts Receivable (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. (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. The purchased accounts receivable are initially recorded at fair value using a market approach based on th e purchase price paid and are classified as Level 2 in the f air value hierarchy. During 2015 , 2014 and 2013 , PPL Electric purchased $ 1.3 b illion , $ 1.1 b illion and $ 985 million of accounts receivable from unaffiliated third parties. During 2015 , 2014 and 2013 , PPL Electric purchased $ 146 million , $ 336 million and $ 294 million of accounts receivable from PPL EnergyPlus . PPL Electric's purchases from PPL EnergyPlus for 2015 include purchases through May 31, 2015, which is the period during which PPL Electric and PPL EnergyPlus were affiliated ent ities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL Electric's purchases from Talen Energy Marketing subsequent t o May 31, 2015 are included as purchases from an unaffiliated third party. Allowance for Doubtful Accounts (All Registrants) Accounts receivable collectability is evaluated using a combination of factors, including past due status based on contractual terms, trends in write-offs, the age of the receivable, counterparty creditworthiness and economic conditions. Specific events, such as bankruptcies, are also considered. Adjustments to the allowance for doubtful accounts are made when necessary based on the results of analysis, the aging of receivables and historical and industry trends. Accounts receivable are written off in th e period in which the receivable is deemed uncollectible. Recoveries of accounts receivable previously written off are recorded when it is known they will be received. The changes in the allowance for doubtful accounts were: Additions Balance at Charged to Balance at Beginning of Period Charged to Income Other Accounts Deductions (a) End of Period PPL 2015 $ 44 $ 49 $ (2) $ 50 $ 41 2014 43 49 48 44 2013 41 38 4 (b) 40 43 PPL Electric 2015 $ 17 $ 39 $ 40 $ 16 2014 18 34 35 17 2013 18 32 32 18 LKE 2015 $ 25 $ 9 $ (2) $ 9 $ 23 2014 22 14 11 25 2013 19 4 4 (b) 5 22 LG&E 2015 $ 2 $ 2 $ 3 $ 1 2014 2 5 $ (1) (b) 4 2 2013 1 2 1 (b) 2 2 KU 2015 $ 2 $ 5 $ 5 $ 2 2014 4 8 $ (3) (b) 7 2 2013 2 3 3 (b) 4 4 (a) Primarily related to uncollectible accounts written off. (b) Primarily related to capital projects, thus the provision was recorded as an adjustment to construction work in progress . Cash Cash Equivalents (All Registrants) All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. Restricted Cash and Cash Equivalents (PPL and PPL Electric) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. The change in restricted cash and cash equivalents is reported as an investing activity on the Statements of Cash Flows. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets" , while the noncurrent portion is included in "Other noncurrent ass ets. " At December 31, the balances of restricted cash and cash equivalents included the following. PPL PPL Electric 2015 2014 2015 2014 Low carbon network fund (a) $ 22 $ 19 Other 11 12 $ 2 $ 3 $ 33 $ 31 $ 2 $ 3 ( a ) Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment. Fair Value Measurements ( All Registrants ) The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securitie s in defined benef it plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows:  Level 1 - q uoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pr icing information on an ongoing basis.  Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability.  Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value. Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liabili ty. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy. Investments ( All Registrants ) Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term. Short-term Investments Short-term investments generally inc lude certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturi ties of greater than a year that management has the ability a nd intent to sell within a year, are included in “Short-term investments” (“Other current assets” if not significant ) on the Balance Sheets. Cost Method Investment ( PPL, LKE, LG&E and KU) LG&E and KU each have an investment in OVEC, which is accounted for using the cost method. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E’s and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of t heir investments; however, LG&E and KU are conditionally responsible for a pro-rata share of certain OVEC obligations. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting reg ulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 13 and 18 for additional discussion of the power purchase agreement. Long-Lived and Intangible Assets Property, Plant and Equipment ( All Registrants ) PP&E is recorded at original cost, unless impaired. PP&E acquired in business combinations is recorded at fair value at the time of acquisition, which establishes its original cost. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which the cost s are incurred. No costs associated with planned major maintenance projects are accrued in advance of the period in which the work is performed. LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. See "Asset Retirement Obligations" below and Note 6 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices. AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC, except for certain instanc es in KU’s FERC approved rates charged to its municipal customers, as a return is provided on construction work in progress . (PPL) PPL capitalizes interest costs as part of construction cost s. Capitalized interest, including the debt component of AFUDC for PPL, was as fo llows. PPL 2015 $ 11 2014 16 2013 15 Depreciation (All Registrants) Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired , the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators. The f ollowing percentages are the weighted- average annu al rates of depreciation at December 31. 2015 PPL PPL Electric LKE LG&E KU Regulated utility plant 2.57 2.46 3.69 3.65 3.71 2014 PPL PPL Electric LKE LG&E KU Regulated utility plant 2.92 2.46 3.80 4.05 3.63 (PPL) Effective January 1, 2015, after completing a review of the useful lives of its distribution network assets, WPD extended the weighted average useful lives of these assets to 69 years from 55 years for GAAP reporting of depreciation expense . For 2015 , this change in useful lives resulted in lower depreciation expense of $ 84 million ($ 66 million after-tax or $ 0.10 per share). (All Registrants) Goodwill and Other Intangible Assets Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination. Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets. When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider the expected use of the asset; the expected useful life of other assets to which the useful life of the intangible asset may relate; legal, r

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2015
Segment and Related Information [Abstract]
Segment and Related Information	2. Segment and Related Information (PPL) PPL is organized into three segments: U.K. Regulated , Kentucky Regulated and Pennsylvania Regulated . PPL’s segments are segmented by geographic location. The U.K. Regulated segment c onsists of PPL Global which primarily includes WPD's regulated electricity distribution operations , the results of hedging the translation of WPD’s earnings from British pound sterling into U.S. dollars, and certain costs, such as U.S. income taxes, administrative costs, and allocated financing costs. T he Kentucky Regulated segment consists primarily of LKE ’s regulated electricity generation , transmission and distribution operations of LG&E and KU, as well as LG&E’s regulated distribution and sale of natural gas. In addition, certain financing costs are allocated t o the Kentucky Regulated segment . The Pennsylvania Regulated segment consists of PPL Electric, a regulated public utility engaged in the distribution and transmission of electricity. "Corporate and Other" primarily includes financing costs incurred at the corporate level that have not been allocated or assigned to the segments, as well as certain other unallocated costs, which is presented to reconcile segment information to PPL’s consolidated results. On June 1, 2015, PPL completed the spinoff of PPL Energy Supply, which substantially represented PPL’s Supply segment. As a result of this transaction, PPL no longer has a Supply segment. See Note 8 for additional information. Financial data for the segments are: Income Statement Data 2015 2014 2013 Operating Revenues from external customers (a) U.K. Regulated $ 2,410 $ 2,621 $ 2,403 Kentucky Regulated 3,115 3,168 2,976 Pennsylvania Regulated 2,124 2,044 1,870 Corporate and Other 20 19 14 Total $ 7,669 $ 7,852 $ 7,263 Depreciation U.K. Regulated $ 242 $ 337 $ 300 Kentucky Regulated 382 354 334 Pennsylvania Regulated 214 185 178 Corporate and Other 45 47 31 Total $ 883 $ 923 $ 843 Amortization (b) U.K. Regulated $ 6 $ 17 $ 19 Kentucky Regulated 27 25 22 Pennsylvania Regulated 26 19 19 Corporate and Other 4 6 Total $ 59 $ 65 $ 66 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ (88) $ (199) $ 44 Kentucky Regulated 11 12 12 Total $ (77) $ (187) $ 56 Interest Expense U.K. Regulated $ 417 $ 461 $ 425 Kentucky Regulated 232 219 212 Pennsylvania Regulated 130 122 108 Corporate and Other 92 41 33 Total $ 871 $ 843 $ 778 Income from Continuing Operations Before Income Taxes U.K. Regulated $ 1,249 $ 1,311 $ 993 Kentucky Regulated 547 501 484 Pennsylvania Regulated 416 423 317 Corporate and Other (d) (144) (106) (66) Total $ 2,068 $ 2,129 $ 1,728 Income Taxes (e) U.K. Regulated $ 128 $ 329 $ 71 Kentucky Regulated 221 189 179 Pennsylvania Regulated 164 160 108 Corporate and Other (d) (48) 14 2 Total $ 465 $ 692 $ 360 Deferred income taxes and investment tax credits (f) U.K. Regulated $ 45 $ 94 $ (45) Kentucky Regulated 236 449 254 Pennsylvania Regulated 220 87 127 Corporate and Other (d) (73) 36 51 Total $ 428 $ 666 $ 387 Net Income U.K. Regulated $ 1,121 $ 982 $ 922 Kentucky Regulated 326 312 307 Pennsylvania Regulated 252 263 209 Corporate and Other (d) (96) (120) (68) Discontinued Operations (g) (921) 300 (240) Total $ 682 $ 1,737 $ 1,130 Cash Flow Data 2015 2014 2013 Expenditures for long-lived assets U.K. Regulated $ 1,242 $ 1,438 $ 1,280 Kentucky Regulated 1,210 1,262 1,434 Pennsylvania Regulated 1,107 957 942 Corporate and Other 11 66 26 Total $ 3,570 $ 3,723 $ 3,682 As of December 31, 2015 2014 Balance Sheet Data Total Assets U.K. Regulated $ 16,669 $ 15,944 Kentucky Regulated 13,756 13,022 Pennsylvania Regulated 8,511 7,706 Corporate and Other (h) 365 909 Discontinued Operations 11,025 Total $ 39,301 $ 48,606 2015 2014 2013 Geographic Data Revenues from external customers U.K. $ 2,410 $ 2,621 $ 2,403 U.S. 5,259 5,231 4,860 Total $ 7,669 $ 7,852 $ 7,263 As of December 31, 2015 2014 Long-Lived Assets U.K. $ 12,487 $ 11,942 U.S. 18,569 16,890 Total $ 31,056 $ 28,832 (a) See Note 1 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of regulatory assets, debt discounts and premiums, debt issuance costs, emission allowances and RECs. (c) Includes unrealized gains and losses from economic activity. See Note 17 for additional information. (d) 2015 and 2014 include certain costs related to the spinoff of PPL Energy Supply, including deferred income tax expense, transition cost s and separation benefits for PPL Services employees. See Note 8 for additional information. (e) Represents both current and deferred income taxes , including investment tax credits. (f) Represents a non-cash expense item that is also incl uded in "Income Taxes.” (g) 2015 includes an $879 million loss on the spinoff of PPL Energy Supply and five months of Supply segment earnings. 2014 includes a gain of $237 million ($137 million after-tax) on the sale of the Montana hydroelectric gener ating facilities. 2013 includes a charge of $697 million ($413 million after-tax) for the termination of the lease of the Colstrip coal-fired electric generating facility. See Note 8 for additional information on these transactions. (h) 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 in to a single reportable segment. LKE, LG&E and KU each operate within a single operating segment.

Preferred Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2015
Preferred Securities [Line Items]
Preferred Securities	3. Preferred Securities (PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2015 , 2014 or 2013 . (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2015 , 2014 or 2013 . Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference s tock. (LG&E) LG&E is authorized to issue up to 1,720,000 sh ares of preferred stock at a $ 25 par value and 6,750,000 shares of preferred stock without par value . LG&E had no preferred stock issued or outstanding in 2015 , 2014 or 2013 . (KU) K U is authorized to issue up to 5,300,000 shares of pref erred stock and 2,000,000 shares of preference stock without par value . KU had no preferred or preference stock issued or outstanding in 2015 , 2014 or 2013 .
PPL Electric Utilities Corp [Member]
Preferred Securities [Line Items]
Preferred Securities	3. Preferred Securities (PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2015 , 2014 or 2013 . (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2015 , 2014 or 2013 . Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference s tock. (LG&E) LG&E is authorized to issue up to 1,720,000 sh ares of preferred stock at a $ 25 par value and 6,750,000 shares of preferred stock without par value . LG&E had no preferred stock issued or outstanding in 2015 , 2014 or 2013 . (KU) K U is authorized to issue up to 5,300,000 shares of pref erred stock and 2,000,000 shares of preference stock without par value . KU had no preferred or preference stock issued or outstanding in 2015 , 2014 or 2013 .
Louisville Gas And Electric Co [Member]
Preferred Securities [Line Items]
Preferred Securities	3. Preferred Securities (PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2015 , 2014 or 2013 . (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2015 , 2014 or 2013 . Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference s tock. (LG&E) LG&E is authorized to issue up to 1,720,000 sh ares of preferred stock at a $ 25 par value and 6,750,000 shares of preferred stock without par value . LG&E had no preferred stock issued or outstanding in 2015 , 2014 or 2013 . (KU) K U is authorized to issue up to 5,300,000 shares of pref erred stock and 2,000,000 shares of preference stock without par value . KU had no preferred or preference stock issued or outstanding in 2015 , 2014 or 2013 .
Kentucky Utilities Co [Member]
Preferred Securities [Line Items]
Preferred Securities	3. Preferred Securities (PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2015 , 2014 or 2013 . (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2015 , 2014 or 2013 . Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference s tock. (LG&E) LG&E is authorized to issue up to 1,720,000 sh ares of preferred stock at a $ 25 par value and 6,750,000 shares of preferred stock without par value . LG&E had no preferred stock issued or outstanding in 2015 , 2014 or 2013 . (KU) K U is authorized to issue up to 5,300,000 shares of pref erred stock and 2,000,000 shares of preference stock without par value . KU had no preferred or preference stock issued or outstanding in 2015 , 2014 or 2013 .

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2015
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 securit ies were converted to common shares as calculated using the T reasury S tock M ethod or If-Converted Method, as applicable . Incremental non-participating securities that have a dilutive impact are detailed in the table below. Reconciliations of the amoun ts of income and shares of PPL common stock (in thousands) for the periods ended December 31 used in the EPS calculation are: 2015 2014 2013 Income (Numerator) Income from continuing operations after income taxes $ 1,603 $ 1,437 $ 1,368 Less amounts allocated to participating securities 6 7 7 Income from continuing operations after income taxes available to PPL common shareowners - Basic 1,597 1,430 1,361 Plus interest charges (net of tax) related to Equity Units (a) 9 44 Income from continuing operations after income taxes available to PPL common shareowners - Diluted $ 1,597 $ 1,439 $ 1,405 Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ (921) $ 300 $ (238) Net income $ 682 $ 1,737 $ 1,130 Less amounts allocated to participating securities 2 9 6 Net income available to PPL common shareowners - Basic 680 1,728 1,124 Plus interest charges (net of tax) related to Equity Units (a) 9 44 Net income available to PPL common shareowners - Diluted $ 680 $ 1,737 $ 1,168 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 669,814 653,504 608,983 Add incremental non-participating securities: Share-based payment awards (b) 2,772 1,910 1,062 Equity Units (a) 10,559 52,568 Forward sale agreements and purchase contracts (b) 460 Weighted-average shares - Diluted EPS 672,586 665,973 663,073 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 2.38 $ 2.19 $ 2.24 Income (loss) from discontinued operations (net of income taxes) (1.37) 0.45 (0.39) Net Income $ 1.01 $ 2.64 $ 1.85 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 2.37 $ 2.16 $ 2.12 Income (loss) from discontinued operations (net of income taxes) (1.36) 0.45 (0.36) Net Income $ 1.01 $ 2.61 $ 1.76 (a) In 2014 and 2013, t he If-Converted Method was applied to the Equ ity Units prior to settlement . See Note 7 for additional information on the Equity Units, including the issuance of PPL common stock to settle the Purchase contracts. (b) The Treasury Stock Method was applied to non-participating share-based payment awards and forward sale agreement s. For the year ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousan ds): 2015 Stock-based compensation plans (a) 4,853 DRIP 1,728 (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 ATM Program. For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive . 2015 2014 2013 Stock options 1,087 1,816 4,446 Performance units 36 5 55 Restricted stock units 31 29

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2015
Income and Other Taxes [Abstract]
Income and Other Taxes	5 . Income and Other Taxes ( PPL ) "Income from Continuing Operations Before Income Taxes" inc luded the following . 2015 2014 2013 Domestic income $ 968 $ 922 $ 669 Foreign income 1,100 1,207 1,059 Total $ 2,068 $ 2,129 $ 1,728 Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes and the tax effects of net operating loss and tax credit carryforwards. The provision for PPL's deferred income taxes for regulated asset s and liabilities is based upon the ratemaking principles of the applicable jurisdiction. See Notes 1 and 6 for additional information. Net deferred tax assets h ave been recognized based on management's estimates of future taxable income for the U.S. and the U.K. Significant c omponents of PPL's deferred income tax assets and liabili ties were as follows . 2015 2014 Deferred Tax Assets Deferred investment tax credits $ 50 $ 52 Regulatory obligations 123 131 Accrued pension costs 217 200 Federal loss carryforwards (a) 587 129 State loss carryforwards (b) 319 225 Federal and state tax credit carryforwards 201 196 Foreign capital loss carryforwards 387 446 Foreign loss carryforwards 4 6 Foreign - pensions 171 182 Foreign - regulatory obligations 12 23 Foreign - other 8 11 Contributions in aid of construction 139 138 Domestic - other 209 194 Unrealized losses on qualifying derivatives 15 46 Valuation allowances (b) (662) (622) Total deferred tax assets 1,780 1,357 Deferred Tax Liabilities Domestic plant - net 3,875 3,079 Taxes recoverable through future rates 162 156 Other regulatory assets 332 322 Reacquired debt costs 28 31 Foreign plant - net 777 854 Domestic - other 24 17 Total deferred tax liabilities 5,198 4,459 Net deferred tax liability $ 3,418 $ 3,102 (a ) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments. ( b) Includes $77 million of deferred tax assets related to state loss carryforwards and related valuation allowances previously reflected on the PPL Energy Supply Segment. The deferred tax assets and related valuation allowance remain with PPL after the spino ff. State d eferred taxes are determined on a by entity, by jurisdiction basis. As a result, $22 million of net deferred tax assets are shown as “Other noncurrent assets” on the Ba lance S heet. At December 31, PPL had the following loss and tax cre dit carryforwards . 2015 Expiration Loss carryforwards Federal net operating losses (a) $ 1,660 2029-2035 Federal charitable contributions 15 2020 State net operating losses (a) (b) 5,269 2017-2035 State charitable contributions 34 2016-2020 Foreign net operating losses (c) 21 Indefinite Foreign capital losses (d) 2,152 Indefinite Credit carryforwards Federal investment tax credit 125 2025-2028 Federal alternative minimum tax credit 40 Indefinite Federal - other (e) 29 2016-2035 State - other 5 2022 ( a) Includes an insignificant amount of federal and state net operating loss carryforwards from excess tax deductions related to stock compensation for which a tax benefit will be recorded in Equity when realized. (b) A valuation allowance of $254 million has been recorded against the deferred tax assets for these losse s. (c ) A valuation allowance of $4 million has been recorded against the deferred tax assets for these losses . (d) A valuation allowance of $ 387 million has been reco rded against the deferred tax assets for these losses . (e) A valuation allowance of $ 12 million has been recorded against the deferred tax assets for these credits . State capital loss and foreign tax credit carryforwards were insignificant at December 31, 2015 . Valuation allowances have been established for the amount that, more likely than not, will not be realized. The changes in deferred tax valuation allowances were as follows. Additions Balance at Charged to Balance Beginning Charged Other at End of Period to Income Accounts Deductions of Period 2015 $ 622 $ 24 $ 77 (b) $ 61 (a) $ 662 2014 585 57 6 26 622 2013 632 25 72 (a) 585 (a) The reductions of the U.K. statutory income tax rates in 2015 and 2013 resulted in $44 million and $67 million in reductions in deferred tax assets and the corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for more information on the impact of the U.K. Finance Acts 2015 and 2013. (b) Valuation allowance related to deferred tax assets previously reflected on the PPL Energy Supply Segment. The deferred tax assets and related valuation allowance remain with PP L after the spinoff. PPL Global does not record U.S. income taxes on the undistributed earnings of WPD, with the exception of certain financing entities, as management has determined that the earnings are indefinitely reinvested. Historically, dividends paid by WPD have been distributions from current year's earnings. WPD's long-term working capital forecasts and capital expenditure projections for the foreseeable future require reinvestment of WPD's undistributed earnings, and WPD would have to issue debt or access credit f acilities to fund any distributions in excess of current earnings. Additionally, U.S. long-term working capital forecasts and capital expenditure projections for the foreseeable future do not require or contemplate distributions from WPD in excess of some portion of future WPD earnings. The cumulative undistributed earnings are included in "Earnings Reinvested" on the Balance Sheets. The amounts consi dered indefinitely reinvested at December 31, 2015 and 2014 were $ 4.6 b illi on and $ 3.7 billion, respectively . If the WPD undistributed earnings were remitted as dividends, PPL Global could be subject to additional U.S. taxes, net of allowable foreign tax credits. It is not practicable to estimate the amo unt of additional taxes that could be payable on these foreign earnings in the event of repatriation to the U.S. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Incom e from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (26) $ 18 $ (102) Current - State 25 26 Current - Foreign 89 152 181 Total Current Expense 88 196 79 Deferred - Federal 699 299 259 Deferred - State 68 120 84 Deferred - Foreign 41 96 (53) Total Deferred Expense, excluding operating loss carryforwards 808 515 290 Investment tax credit, net - Federal (4) (5) (5) Tax expense (benefit) of operating loss carryforwards Deferred - Federal (a) (396) 8 14 Deferred - State (31) (22) (18) Total Tax Expense (Benefit) of Operating Loss Carryforwards (427) (14) (4) Total income taxes from continuing operations $ 465 $ 692 $ 360 Total income tax expense - Federal $ 273 $ 320 $ 166 Total income tax expense - State 62 124 66 Total income tax expense - Foreign 130 248 128 Total income taxes from continuing operations $ 465 $ 692 $ 360 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to provision to return adjustments. In the table above, the following income tax expense (benefits) are excluded from income taxes from continuing operations. 2015 2014 2013 Discontinued operations - PPL Energy Supply Segment $ (30) $ 198 $ (180) Stock-based compensation recorded to Additional Paid-in Capital (4) (2) Valuation allowance on state deferred taxes related to issuance costs of Purchase Contracts recorded to Additional Paid-in Capital (2) Other comprehensive income (2) (190) 159 Valuation allowance on state deferred taxes recorded to other comprehensive income (4) (7) Total $ (36) $ 4 $ (32) 2015 2014 2013 Reconciliation of Income Tax Expense Federal income tax on Income from Continuing Operations Before Income Taxes at statutory tax rate - 35% $ 724 $ 745 $ 605 Increase (decrease) due to: State income taxes, net of federal income tax benefit 31 28 17 Valuation allowance adjustments (a) 24 55 24 Impact of lower U.K. income tax rates (b) (176) (180) (144) U.S. income tax on foreign earnings - net of foreign tax credit (c) 8 63 21 Federal and state tax reserves adjustments (d) (22) (1) (49) Impact of the U.K. Finance Acts on deferred tax balances (b) (91) (1) (97) Depreciation not normalized (5) (7) (8) State deferred tax rate change (e) (1) 15 Interest benefit on U.K. financing entities (20) (5) (7) Other (8) (4) (17) Total increase (decrease) (259) (53) (245) Total income taxes from continuing operations $ 465 $ 692 $ 360 Effective income tax rate 22.5% 32.5% 20.8% (a) During 2015, PPL recorded $24 million of deferred income tax expense related to deferred tax valuation allowances. PPL recorded state deferred income tax expense of $12 million primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized and $12 million of federal deferred income tax expense primarily related to federal tax credit carryforwards that are expected to expire as a result of lower future taxable earnings due to the extension of bonus depr eciation. As a result of the PPL Energy Supply spinoff announcement, PPL recorded $50 million of deferred income tax expense during 2014 to adjust the valuation allowance on deferred tax assets primarily for state net operating loss carryforwards that we re previously supported by the future earnings of PPL Energy Supply. See Note 8 for additional information on the spinoff. During 2013, PPL recorded $23 million of state deferred income tax expense related to a deferred tax valuation allowance primarily due to a decrease in projected future taxable income at PPL Energy Supply over the remaining carryforward period of Pennsylvania net operating losses. (b) The U.K. Finance Act 2015 , enacted in November 2015 , reduced the U.K. statutory income tax rate f rom 20% to 1 9% effective April 1, 2017 and from 19 % to 18% effective April 1, 2020 . As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2015 related to both rate decreases. The U.K. Finance Act 2013, enact ed in July 2013, reduced the U.K. statutory income tax rate from 23% to 21% effective April 1, 2014 and from 21% to 20% effective April 1, 2015. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2013 re lated to both rate decreases. (c) During 2015, PPL recorded lower income taxes primarily attributable to a decrease in taxable dividends. During 2014, PPL recorded $47 million of income tax expense primarily attributable to taxable dividends. During 20 13, PPL recorded $28 million of income tax expense resulting from increased taxable dividends offset by a $19 million income tax benefit associated with a ruling obtained from the IRS impacting the recalculation of 2010 U.K. earnings and profits that was r eflected on an amended 2010 U.S. tax return. (d) In 2015, PPL recorded a $12 million tax benefit related to the settlement of the IRS audit for the tax years 1998-2011. In May 2013, the Supreme Court ruled that the U.K. Windfall Profits Tax (WPT) imposed on privatized utilities, including WPD, is a creditable tax for U.S. federal income tax purposes. As a result of the Supreme Court ruling, PPL recorded a tax benefit of $44 million during 2013, of which $19 million relates to int erest. In 2013, PPL r ecorded a federal and state income tax reserve benefit of $7 million related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization was zero. (e) During each period, PPL recorded adjustments related to its December 31 state deferred tax liabilities as a result of annual changes in state apportionment and the impact on the future estimated state income tax rate . 2015 2014 2013 Taxes, other than income State gross receipts (a) $ 89 $ 102 $ 98 Foreign property 148 157 147 Domestic Other 62 58 53 Total $ 299 $ 317 $ 298 (a) The decrease in 2015 was primarily due to the settlement of a 2011 gross receipts tax audit resulting in the reversal of $17 million of previously recognized reserves. ( PPL Electric) The provision for PPL Electric's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the PUC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that ot herwise would be recorded under GAAP is d eferred and included in " Regulatory assets " or "Regulated liabilities" on the Balance Sheet s . Significant components of PPL Electric's deferred income tax assets and liabilities were as follows . 2015 2014 Deferred Tax Assets Accrued pension costs $ 92 $ 85 Contributions in aid of construction 111 110 Regulatory obligations 56 39 State loss carryforwards 27 30 Federal loss carryforwards (a) 146 51 Other 87 54 Total deferred tax assets 519 369 Deferred Tax Liabilities Electric utility plant - net 1,803 1,453 Taxes recoverable through future rates 135 132 Reacquired debt costs 18 20 Other regulatory assets 213 173 Other 13 16 Total deferred tax liabilities 2,182 1,794 Net deferred tax liability $ 1,663 $ 1,425 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments . At December 31, PPL Electric had the following loss carryforwards. 2015 Expiration Loss carryforwards Federal net operating losses $ 411 2031-2035 Federal charitable contributions 3 2020 State net operating losses 410 2030-2032 State charitable contributions 13 2016-2020 Credit carryforwards were insignificant at December 31, 2015 . Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (80) $ 60 $ (15) Current - State 23 15 (4) Total Current Expense (Benefit) (57) 75 (19) Deferred - Federal 287 70 109 Deferred - State 12 16 16 Total Deferred Expense, excluding operating loss carryforwards 299 86 125 Investment tax credit, net - Federal (1) (1) Tax expense (benefit) of operating loss carryforwards Deferred - Federal (75) 4 Deferred - State (3) (1) Total Tax Expense (Benefit) of Operating Loss Carryforwards (78) 3 Total income tax expense $ 164 $ 160 $ 108 Total income tax expense - Federal $ 132 $ 129 $ 97 Total income tax expense - State 32 31 11 Total income tax expense $ 164 $ 160 $ 108 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 146 $ 148 $ 111 Increase (decrease) due to: State income taxes, net of federal income tax benefit 25 22 16 Federal and state tax reserves adjustments (a) 2 (1) (9) Federal and state income tax return adjustments (2) 1 (1) Depreciation not normalized (4) (6) (6) Other (3) (4) (3) Total increase (decrease) 18 12 (3) Total income tax expense $ 164 $ 160 $ 108 Effective income tax rate 39.4% 37.8% 34.1% (a) PPL Electric recorded a tax benefit of $7 million during 2013 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization wa s zero. 2015 2014 2013 Taxes, other than income State gross receipts (a) $ 89 $ 102 $ 98 Property and other 5 5 5 Total $ 94 $ 107 $ 103 (a) The decrease in 2015 was primarily due to the settlement of a 2011 gross receipts tax audit resulting in the reversal of $17 million of previously recognized reserves. (LKE) The provision for LKE’s deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflect ed in rates established by the KPSC, VSCC, TRA and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities " on the Bala nce Sheets. Significant components of LKE's deferred income tax assets and liabilities were as follows. 2015 2014 Deferred Tax Assets Federal loss carryforwards (a) $ 280 $ 46 State loss carryforwards 35 36 Tax credit carryforwards 181 182 Regulatory liabilities 66 92 Accrued pension costs 53 53 Income taxes due to customers 17 20 Deferred investment tax credits 50 51 Derivative liability 18 45 Other 55 44 Valuation allowances (12) Total deferred tax assets 743 569 Deferred Tax Liabilities Plant - net 2,076 1,639 Regulatory assets 119 143 Other 11 12 Total deferred tax liabilities 2,206 1,794 Net deferred tax liability $ 1,463 $ 1,225 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments . LKE expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. At December 31, LKE had the following loss and tax credit carryforwards . 2015 Expiration Loss carryforwards Federal net operating losses $ 801 2029-2035 State net operating losses 934 2028-2035 State capital losses 1 2016 Credit carryforwards Federal investment tax credit 125 2025-2028 Federal alternative minimum tax credit 28 Indefinite Federal - other 27 2016-2035 State - other 5 2022 Changes in deferred tax valuation allowances were : Balance at Balance Beginning at End of Period Additions Deductions of Period 2015 $ 12 (a) $ 12 2014 $ 4 $ 4 (b) 2013 5 1 (b) 4 (a) Represents tax credits expiring in 2016 through 2020 that are more likely than not to expire before being utilized. (b) Primarily related to the expiration of state capital loss carryforwards . Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ 2 $ (247) $ (59) Current - State 1 8 10 Total Current Expense (Benefit) 3 (239) (49) Deferred - Federal 405 437 244 Deferred - State 32 23 20 Total Deferred Expense, excluding benefits of operating loss carryforwards 437 460 264 Investment tax credit, net - Federal (3) (4) (4) Tax benefit of operating loss carryforwards Deferred - Federal (198) (8) (4) Deferred - State (1) Total Tax Benefit of Operating Loss Carryforwards (198) (8) (5) Total income tax expense from continuing operations (a) $ 239 $ 209 $ 206 Total income tax expense - Federal $ 206 $ 178 $ 177 Total income tax expense - State 33 31 29 Total income tax expense from continuing operations (a) $ 239 $ 209 $ 206 ( a) Excludes current and deferred federal and state tax expense (benefit) recorded to Discontinued Operations of less than $1 million in 2015 and 2014, and $1 million in 201 3. Also, e xcludes deferred federal and state tax expense (benefit) recorded to OCI of less than $( 1) million in 2015, $(36) million in 2014 and $18 million in 201 3. 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 211 $ 194 $ 193 Increase (decrease) due to: State income taxes, net of federal income tax benefit 22 20 20 Amortization of investment tax credit (3) (4) (4) Valuation allowance adjustment (a) 12 Other (3) (1) (3) Total increase (decrease) 28 15 13 Total income tax expense from continuing operations $ 239 $ 209 $ 206 Effective income tax rate 39.6% 37.8% 37.4% ( a) Represents a valuation allowance against tax credits expiring from 2016 through 2020 that are more likely than not to expire before being utilized. 2015 2014 2013 Taxes, other than income Property and other $ 57 $ 52 $ 48 Total $ 57 $ 52 $ 48 (LG&E) The provision for LG&E's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of LG&E's deferred income tax assets and liabilities were as follows. 2015 2014 Deferred Tax Assets Federal loss carryforwards (a) $ 76 Regulatory liabilities 38 $ 51 Deferred investment tax credits 13 14 Income taxes due to customers 17 18 Derivative liability 18 32 Other 15 9 Total deferred tax assets 177 124 Deferred Tax Liabilities Plant - net 896 698 Regulatory assets 75 90 Accrued pension costs 28 28 Other 7 8 Total deferred tax liabilities 1,006 824 Net deferred tax liability $ 829 $ 700 (a) Increase in Federal loss carryforwards primarily relates to the e xtension of bonus depreciation. LG&E expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. At December 31, 2015 , LG&E had $ 218 million of federal net operating loss carryforwards that expire in 2035 , $ 1 million of federal credit carryforwards that expire from 2031 to 2035 and $ 2 million of state credit carryforwards that expire in 2022 . Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (15) $ (25) $ 52 Current - State 3 10 16 Total Current Expense (Benefit) (12) (15) 68 Deferred - Federal 190 114 33 Deferred - State 13 6 (2) Total Deferred Expense, excluding benefits of operating loss carryforwards 203 120 31 Investment tax credit, net - Federal (1) (2) (2) Tax benefit of operating loss carryforwards Deferred - Federal (76) (3) Total Tax Benefit of Operating Loss Carryforwards (76) (3) Total income tax expense $ 114 $ 103 $ 94 Total income tax expense - Federal $ 98 $ 87 $ 80 Total income tax expense - State 16 16 14 Total income tax expense $ 114 $ 103 $ 94 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 105 $ 95 $ 90 Increase (decrease) due to: State income taxes, net of federal income tax benefit 11 10 10 Amortization of investment tax credit (1) (2) (2) Other (1) (4) Total increase (decrease) 9 8 4 Total income tax expense $ 114 $ 103 $ 94 Effective income tax rate 38.1% 37.9% 36.6% 2015 2014 2013 Taxes, other than income Property and other $ 28 $ 25 $ 24 Total $ 28 $ 25 $ 24 ( KU ) The provision for KU's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC, VSCC, TRA and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or " Regulatory liabilities" on the Balance Sheets. Significant components of KU's deferre d income tax assets and liabilities were as follows . 2015 2014 Deferred Tax Assets Federal loss carryforwards (a) $ 97 Regulatory liabilities 28 $ 41 Deferred investment tax credits 36 37 Income taxes due to customers 2 Derivative liability 13 Other 7 7 Total deferred tax assets 168 100 Deferred Tax Liabilities Plant - net 1,164 922 Regulatory assets 44 53 Other 6 7 Total deferred tax liabilities 1,214 982 Net deferred tax liability $ 1,046 $ 882 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation. KU expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. At December 31, 2015 , KU had $ 279 million of federal net operating loss carryforwards that expire in 2035 and $ 2 million of state credit carryforwards that expire in 2022 . Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (21) $ (95) $ 51 Current - State 1 6 12 Total Current Expense (Benefit) (20) (89) 63 Deferred - Federal 240 212 66 Deferred - State 19 14 8 Total Deferred Expense, excluding benefits of operating loss carryforwards 259 226 74 Investment tax credit, net - Federal (2) (2) (2) Tax benefit of operating loss carryforwards Deferred - Federal (97) (3) Total Tax Benefit of Operating Loss Carryforwards (97) (3) Total income tax expense (a) $ 140 $ 135 $ 132 Total income tax expense - Federal $ 120 $ 115 $ 112 Total income tax expense - State 20 20 20 Total income tax expense (a) $ 140 $ 135 $ 132 (a) Excludes deferred federal and state tax expense (benefit) recorded to OCI of less than $(1) million in 2015, 2014 and 2013 . 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 131 $ 124 $ 126 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 13 14 Amortization of investment tax credit (2) (2) (2) Other (2) (6) Total increase (decrease) 9 11 6 Total income tax expense $ 140 $ 135 $ 132 Effective income tax rate 37.4% 38.0% 36.7% 2015 2014 2013 Taxes, other than income Property and other $ 29 $ 27 $ 24 Total $ 29 $ 27 $ 24 Unrecognized Tax Benefits ( All Registrants ) PPL or its subsidiaries file tax returns in four major tax jurisdictions. The income tax provision s for PPL Electric , LKE, LG&E and KU are calculated in accordance with an intercompany tax sharing agreement which provides that taxable income be calculated as if each domestic subsidiar y filed a separate consolidated return. Based on this tax sharing agreement, PPL Electric or its subsidiaries indirectly or directly file tax returns in two major tax jurisdictions , and LKE , LG&E and KU or their subsidiaries indirectly or directly file tax returns in two major tax jurisdiction s . With few exceptions, at December 31, 2015 , these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows . PPL PPL Electric LKE LG&E KU U.S. (federal) 2011 and prior 2011 and prior 2011 and prior 2011 and prior 2011 and prior Pennsylvania (state) 2011 and prior 2011 and prior Kentucky (state) 2010 and prior 2010 and prior 2010 and prior 2010 and prior U.K. (foreign) 2012 and prior Other (PPL) In 2 015, PPL recorded a tax benefit of $ 24 million , related to the settlement of the IRS audit for tax years 1998-2011 . Of this amount, $ 12 million is reflected in Income from C ontinuing O perations After Income Taxes .

Utility Rate Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2015
Utility Rate Regulation [Line Items]
Utility Rate Regulation	6 . Utility Rate Regulation Regulatory Assets and Liabilities (All Registrants ) PPL, PPL Electric, LKE, LG&E and KU reflect the effects of regulatory actions in the financial statements for their cost-based rate-regulated utility operations. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to that item will be recovered or refunded within a year of the balance sheet date. WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. See Note 1 for additional information. (PPL, LKE, LG&E and KU) LG&E is subject to the jurisdiction of the K PSC and FERC , and KU is subject to the jurisdiction of the KPSC, FERC, VSCC and TRA . LG&E's and KU's Kentucky base rates are c alculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investmen ts and costs recovered separately through other means . As such, LG&E and KU generally earn a return on regulatory asset s . As a result of purchase accountin g requirements , certain fair value amounts related to contracts that ha d favorable or unfavorable terms relative to market were recorded on the B alance S heet s with an offsetting regulatory asset or liability. L G& E and KU recover in customer rates the cost of coal contracts, power purchases and emission allowances. As a result, management believes the regulatory assets and liabilities created to offset the fair value amounts at LKE's acquisition date meet the recognition criteria established by existing accounting guidance and eliminate any rate- making impact of the fair value adjustments. LG& E's and KU’s customer rates will continue to reflect the original contracted prices for these contracts . (PPL, LKE an d KU) KU's Virginia base rates are calculated based on a return on rate base (net utility plant plus working capital less deferred taxes and miscellaneous deductions). All regulatory assets and liabilities , except the levelized fuel factor, are excluded from the return on rate base utilized in the calculation of Virginia base rates. T herefore, no return is earned on the related assets. KU’s rates to municipal customers for wholesale requirements are calculated based on annual updates to a r ate formula that utilizes a return on rate base (net utility plant plus working capital less deferred taxes and miscellaneous deductions) . All regulatory assets and liabilities are excluded from the return on rate base utilized in the developmen t of munic ipal rates. T herefore, no return is earned on the related assets. (PPL and PPL Electric) PPL Electric's distribution base rates are calculated based on recovery of costs as well as a return on distribution rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions). PPL Electric's transmission revenues are billed in accordance with a FERC tariff that allows for recovery of transmission costs incurred, a return on transmission-related rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions) and an automatic annual update. See "Transmission Formula Rate" below for additional information on this tariff. All regulatory assets and liabilities are excluded from distribution and transmission return on investment calculations; therefore, generally no return is earned on PPL Electric's regulatory assets . ( All Registrants ) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31. PPL PPL Electric 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 Gas supply clause 1 15 Transmission service charge 10 6 $ 10 $ 6 Other 13 11 3 6 Total current regulatory assets (a) $ 48 $ 37 $ 13 $ 12 Noncurrent Regulatory Assets: Defined benefit plans $ 809 $ 720 $ 469 $ 372 Taxes recoverable through future rates 326 316 326 316 Storm costs 93 124 30 46 Unamortized loss on debt 68 77 42 49 Interest rate swaps 141 122 Accumulated cost of removal of utility plant 137 114 137 114 AROs 143 79 Other 16 10 2 Total noncurrent regulatory assets $ 1,733 $ 1,562 $ 1,006 $ 897 Current Regulatory Liabilities: Generation supply charge $ 41 $ 28 $ 41 $ 28 Demand side management 8 2 Gas supply clause 6 6 Transmission formula rate 48 42 48 42 Fuel adjustment clause 14 Storm damage expense 16 3 16 3 Other 12 10 8 3 Total current regulatory liabilities $ 145 $ 91 $ 113 $ 76 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 Coal contracts (b) 17 59 Power purchase agreement - OVEC (b) 83 92 Net deferred tax assets 23 26 Act 129 compliance rider 22 18 $ 22 $ 18 Defined benefit plans 24 16 Interest rate swaps 82 84 Other 3 4 Total noncurrent regulatory liabilities $ 945 $ 992 $ 22 $ 18 LKE LG&E KU 2015 2014 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 $ 13 $ 4 $ 11 $ 1 Gas supply clause 1 15 1 15 Fuel adjustment clause 4 2 2 Gas line tracker 1 1 Other 9 1 1 8 1 Total current regulatory assets $ 35 $ 25 $ 16 $ 21 $ 19 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 340 $ 348 $ 215 $ 215 $ 125 $ 133 Storm costs 63 78 35 43 28 35 Unamortized loss on debt 26 28 17 18 9 10 Interest rate swaps 141 122 98 89 43 33 AROs 143 79 57 28 86 51 Plant retirement costs 6 6 Other 8 10 2 4 6 6 Total noncurrent regulatory assets $ 727 $ 665 $ 424 $ 397 $ 303 $ 268 Current Regulatory Liabilities: Demand side management $ 8 $ 2 $ 4 $ 1 $ 4 $ 1 Gas supply clause 6 6 6 6 Fuel adjustment clause 14 2 12 Gas line tracker 3 3 Other 4 4 1 3 4 Total current regulatory liabilities $ 32 $ 15 $ 13 $ 10 $ 19 $ 5 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 $ 301 $ 302 $ 390 $ 391 Coal contracts (b) 17 59 7 25 10 34 Power purchase agreement - OVEC (b) 83 92 57 63 26 29 Net deferred tax assets 23 26 23 24 2 Defined benefit plans 24 16 24 16 Interest rate swaps 82 84 41 42 41 42 Other 3 4 2 2 1 2 Total noncurrent regulatory liabilities $ 923 $ 974 $ 431 $ 458 $ 492 $ 516 (a ) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. ( b ) These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acq uisition of LKE by PPL. Following is an overview of selected regulatory assets and liabilities detailed in the preceding tables. Specific developments with respect to certain of these regulatory assets and liabilities are discussed in "Regulatory Matters." Defined Benefit Plans (All Registrants) Defined benefit plan regulatory assets and liabilities represent the portion of unrecognized transition obligation, prior service cost and net actuarial gains and losses that will be recovered in defined benefit plans expense thro ugh future base rates based upon established regulatory practices and generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded sta tus of defined benefit plans is re-measured. Of the regulatory asset and liability balances recorded, costs of $ 46 million for PPL, $ 18 million for PPL Electric, $ 28 million for LKE, $ 19 million for LG&E and $ 9 million for KU are expected to be amortized into net periodic defined benefi t costs in 2016 in accordance with PPL's, PPL Electric's, LKE's, LG&E's and KU's pension accounting policy . (PPL, LKE, LG&E and KU ) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between pension cost calculated in accordance with LG&E and KU's pension accounting policy and pension cost calculated using a 15 year amortization period for act uarial gains and losses is recorded as a regulatory asset. As of December 31, 2015 , the balance s were $ 10 million for PPL and LKE, $ 6 million for LG&E and $ 4 million for KU . Of the costs expected to be amortized into net periodic defined benefit costs in 2016 , $ 10 million for PPL and LKE, $ 6 million for LG&E and $ 4 million for KU are expected to be recorded as a regulatory asset in 2016 . (All Registrants) Storm Costs PPL Electric, LG&E and KU have the ability to request from the PUC, KPSC and VSCC, as applicable, the authority to treat expenses related to specific extraordinary storms as a regulatory asset and defer such costs for regulatory accounting and reporting purposes. Once such authority is granted, LG&E and KU can request recovery of those expenses in a base rate case and begin amortizing the costs when recovery starts . PPL Electric can recover qualifying expenses caused by major storm events, as defined in its retail tariff, over three years through the Storm Damage Expense Rider commencing in the appli cation year after the storm occurred. LG&E's and KU's regulatory assets for storm costs are being amortized through various dates ending in 2020. Unamortized Loss on Debt Unamortized loss on reacquired debt represents losses on long-term debt reacquired or redeemed that have been deferred and will be amortized and recovered over either the original life of the extinguished debt or the life of the replacement debt (in the case of refinancing). Such costs are being amortized through 2029 for PPL Electric, 2035 for LG&E and through 2040 for PPL, LKE and KU. Accumulated Cost of Removal of Utility Plant LG&E and KU accrue for costs of removal through depreciation expense with an offsetting credit to a regulatory liability. The regulatory liability is relieved as costs are incurred. PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the costs as a regulatory asset. Such deferral is included in rates and amortized over the subsequent five -year period. (PPL and PPL Electric) Generation Supply Charge The generation supply charge is a cost recovery mechanism that perm its PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply (energy and capacity and ancillary services), as well as administrati on of the acquisition process. In addition, the generation supply charge contains a reconciliation mechanism whereby any over- or under-recovery from prior quarters is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent quarter. Transmission Service Charge (TSC) PPL Electric is charged by PJM for transmission service-related costs applicable to its PLR customers. PPL Electric passes these costs on to customers, who receive basic generation supply servi ce through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the su bsequent year. Transmission Formula Rate PPL Electric's transmission revenues are billed in accordance with a FERC-approved O pen A ccess T ransmission T ariff that utilizes a formula-based rate recovery mechanism. Under this formula, rates are put into eff ect in June of each year based upon prior year actual expenditures and current year forecasted capital additions. Rates are then adjusted the following year to reflect actual annual expenses and capital additions. Any difference between the revenue requi rement in effect for the prior year and actual expenditures incurred for that year is recorded as a regulatory asset or regulatory liability. Storm Damage Expense In accordance with the PUC's December 2012 final rate case order, PPL Electric proposed the establishment of a Storm Damage Exp ense Rider (SDER) with the PUC. In April 2014, the PUC issued a final order approving the SDER with a January 1, 2015 effective date. On June 20 , 2014, the Office of Consumer Advocate (OCA) filed a petition requesting the Commonwealth Court of Pennsylvania to reverse and remand the April 2014 order, which petition remains outstanding. On January 15, 2015, the PUC issued an order modifying the effective date of the SDER to February 1, 2015. See below under "Regulatory Matters - Pennsylvania Activities" for additional information on the SDER. Taxes Recoverable through Future Rates Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underl ying book-tax timing differences reverse and the actual cash taxes are incurred. Act 129 Compliance Rider In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, Phase I of PPL Electric's energy efficiency and conservation plan wa s approved by a PUC order in October 2009. The order allows PPL Electric to recover the maximum $ 250 million cost of the program ratably over the life of the plan, from January 1, 2010 through May 31, 2013. Phase II of PPL's energy efficiency and conservation plan allows PPL Electric to recover the maximum $ 185 million cost of the program over the three year period June 1, 2013 through May 31, 2016. The plan includes programs intended to reduce electricity consumption. The recoverable costs include direct and indirect charges, including design and development costs, general and administrative costs and applicable state evaluator costs. The rates are applied to customers who receive distribution service through the Act 129 Compliance Rider. The actual program costs are reconcilable, and any over- or under-recovery from customers will be refunded or recovered at the end of the program. See below under "Regulatory Matters - Pennsylvania Activitie s" for additional information on Act 129. (PPL, LKE, LG&E and KU) E nvironmental Cost Recovery Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements which apply to coal combustion wastes and by-products from coal-fired electric generating facilities. The KPSC requires reviews of the past operations of the environmental surcharge for six -month and two -year billing periods to evaluate the related charges, credits and rates of return, as well as to provide for the roll-in of ECR amounts to base rates each two -year period. As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, LG&E and KU were authorized to earn a 10% return on equ ity for all their existing ECR plans . The ECR regulatory asset or liability represents the amount that has been under- or over-recovered due to timing or adjustments to the mechanism and is typically recovered within 12 months. Gas Supply Clause LG&E's natural gas rates contain a gas supply clause, whereby the expected cost of natural gas supply and variances between actual and expected costs from prior periods are adjusted quarterly in LG&E's rates, subject to approval by the KPSC. The gas supply clause includes a separate natural gas procurement incentive mechanism, which allows LG&E's rates to be adjusted annually to share variances between actual costs and market indices between the shareholders and the customers during each performance-based rate year ( 12 months ending October 31) . The regulatory assets or liabilities re present the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered within 18 months. Fuel Adjustment Clauses LG&E's and KU's retail electric rates contain a fuel adjustment clause , whereby variances in the cost of fuel to generate electric ity , including transportation costs, from the cost s embedded in base rates are adjusted in LG&E's and KU’s rates. The KPSC requires public hearings at six -month intervals to examine past fuel adjustments and at two -year intervals to rev iew past operations of the fuel adjustment clause and , to the extent appropriate , reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjus tments to the mechanism and are typically recovered within 12 months . KU also employs a levelized fuel factor mechanism for Virginia customers using an average fuel cost factor based primarily on projected fuel costs. The Virginia levelized fuel factor allows fuel recovery based on projected fuel costs for the coming year plus an adjustment for any under- or over-recovery of fuel expenses from the prior year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months . Demand Side Management LG&E's and KU's DSM programs consist of energy efficiency programs whic h are intended to reduce peak demand and delay the investment in additional power plant construction, provide customers with tools and information to become better managers of their energy usage and prepare for potential future legislation governing energy efficiency. LG&E 's and KU 's rates contain a DSM provision which includes a rate recovery mechanism that provides for concurrent recovery of DSM costs and incentives , and allows for the recovery of DSM revenues from lost sales associated with the DSM programs. Additionally , LG&E and KU earn an approved r eturn on e quity for capital expenditures associated with the r esidential and c ommercial l oad m anagement/ d emand c ons ervation p rograms. The cost of DSM programs is assigned only to the class or classes of customers that benefit from the programs. Interest Rate Swaps (PPL, LKE, LG&E and KU) Periodically, LG&E and KU enter into forward-starting interest rate swaps wit h PPL that have terms identical to forward-starting swaps entered into by PPL with third parties. Net realized gains and losses on all of these swaps are probable of recovery through regulated rates; as such, any gains and losses on these derivatives are included in regulatory assets or liabilities and will be recognized in “Interest Expense” on the Statements of Income over the life of the underlying debt at the time the underlying hedged interest expense is recorded. In September 2015, first mortgage bo nds totaling $ 1.05 billion were issued (LG&E issued $ 550 million and KU issued $ 500 million) and all outstanding forward-starting interest rate swaps were terminated. Net cash settlements of $ 88 million were paid on the swaps that were terminated (LG&E and KU each paid $ 44 million). Net realized losses on these terminated swaps will be recovered through regulated ra tes. As such, the net settlements were recorded in regulatory assets and are being recognized in "Interest Expense" on the Statements of Income over the life of the new debt that matures in 2025 and 2045 . There were no forward starting interest rate swaps outstanding at December 31, 2015 . See Note 17 for additional information related to the forwa rd-starting interest rate swaps . Net cash settlements of $ 86 million were received on forward starting interest rate swaps that were terminated in 2013 (LG&E and KU each received $ 43 million). Net realized gains on these terminated swaps will be returned through regulated rates. As such, the net settlements were recorded as regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the associated debt that matures in 2043 . (PPL, LKE and LG&E) In additio n to the terminated forward starting interest rate swaps, realized amounts associated with LG&E's other interest rate swaps, including a terminated swap contract from 2008 , are recoverable through rates based on an o rder from the KPSC, LG&E's unrealized lo sses and gains are recorded as a regulatory asset or liability until they are realized as interest expense. Interest expense from existing swaps is realized and recovered over the terms of the associated debt, which matures through 2033 . Amortization of the gain or loss related to the 2008 terminated swap contract is to be recovered through 2035 . AROs As discussed in Note 1, the accretion and depreciation expenses related to LG&E’s and KU’s AROs are recorded as a regulatory asset, such that there is no earnings impact. When an asset with an ARO is retired, th e related ARO regulatory asset is offse t against the associated cost of removal regulatory liability, PP&E and ARO liability. Gas Line Tracker T he GLT authorizes LG&E to recover its incremental operating expenses, depreciation, property taxes, and its cost of capital including a return on equity for capital associated with the five year gas service riser, leak mitigation and customer service line ownership programs. As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, LG&E is authorized to earn a 10% return on equity for the GLT mechanism . As part of thi s program, LG&E makes necessary repairs and assumes ownership of natural gas lines. LG&E annually files projected costs in October to become effective on the first billing cycle in January. After the completion of a plan year, LG&E submits a balancing ad justment filing to the KPSC to amend rates charged for the differences between the actual costs and actual GLT charges for the preceding year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to these timing differences. Coal Contracts As a result of purchase accounting associated with PPL's acquisition of LKE, LG&E's and KU's coal contracts were recorded at fair value on the Balance Sheets with offsets to regulatory assets for those contracts with un favorable terms relative to current market prices and offsets to regulatory liabilities for those contracts with favorable terms relative to current market prices . The se regulatory assets and liabilities are being amortized over the same terms as the related contracts, which expire at various times through 2016 . Power Purchase Agreement - OVEC As a result of purchase accounting associated with PPL's acquisition of LKE, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of LKE, LG&E and KU with offsets to regulatory liabilities. The regulatory liabilities ar e being amortized using the units-of-production method until March 2026 , the expiration date of the agreement at the date of the acquisition . Regulatory Liability A ssociated with Net Deferred Tax Assets LG&E's and KU's r egulatory liabilities associated with net deferred tax assets represent the future revenue impact from the reversal of deferred income taxes required primarily for unamortized investment tax credits. These regulatory liabilities are recognized when the of fsetting deferred tax assets are recognized. Plant Retirement Costs The 2014 Kentucky rate case settlement that became effective July 1, 2015, provided for deferred recovery of costs associated with Green River's remaining coal-fired generating units t hrough their retirement date, which occurred in September 2015 . These costs include inventory write-downs and separation benefits and will be amortized over three years. R egulatory Matters U.K. Activities (PPL) RIIO-ED1 On April 1, 2015, the RIIO-ED1 eight-year price control period commenced for WPD's four DNOs. Ofgem Review of Line Loss Calculation In 2014, Ofgem issued its final decision on the DPCR4 line loss incentives and penalties mechanism. As a result, during 2014 WPD increased its liability by $ 65 million for over-recovery of line losses with a reduction to " Operating Revenues " on the Statement of Income. In 2013 , WPD had recorded an increase of $45 million to the liability with a reduction to "Operating Revenues" on the Statement of Income . O ther activity impacting the liability included reductions in the liability that have been included in tariffs and foreign exchange movements. WPD began refunding the liability to customers on April 1, 2015 and will continue through March 31, 201 9. The liability at December 31, 2015 and 2014 was $ 61 million and $ 99 million . Kentucky Activities (PPL, LKE, LG&E and KU) Rate Case Proceedings On June 30, 2015, the KPSC approved a rate case settlement agreement providing for increases in the annual revenue requirements associated with KU base electricity rates of $ 125 million and LG&E base gas rates of $ 7 million. The annual revenue requirement associated with base electricity rates at LG&E was not changed. Although the settlement did not establish a specific return on equity with respect to the base rates, an authorized 10% return on equity will be utilized in the ECR and GLT mechanisms. The settlement agreement provides for deferred recovery of costs associated with KU's retire ment of Green River Units 3 and 4 . The new regulatory asset will be amortized over three years. The settlement also provides regulatory asset treatment for the difference between pension expense calculated in accordance with LG&E and KU’s pension accounting policy and pension expense using a 15 year amortization period for actuarial gains and losses. The new rates and all elements of the settlement became effective July 1, 2015. KPSC Landfill Proce edings On May 22, 2015, LG&E and KU filed an application with the KPSC for a declaratory order that the existing CPCN and ECR approvals regarding the initial phases of construction and rate recovery of the landfill for management of CCRs at the Trimble C ounty Station remain in effect. The current design of the proposed landfill provides for construction in substantially the same location as originally proposed with approximately the same storage capacity and expected useful life. On May 20, 2015, the ow ner of an underground limestone mine filed a complaint with the KPSC requesting it to revoke the CPCN for the Trimble County landfill and limit recovery of costs for the Ghent Station landfill on the grounds that, as a result of cost increases, the propose d landfill no longer constitutes the least cost alternative for CCR management. The KPSC has initiated its own investigation, consolidated the proceedings, and ordered an accelerated procedural schedule. The KPSC conducted a hearing on the matter in Sept ember 2015 . On December 15, 2015, the KPSC issued an order affirming LG&E and KU's existing CPCN and ECR authority for Phase 1 of the Trimble County and Ghent landfills and related facilities, and that the landfills are the least cost options for disposin g of the combustion wastes. Additionally, the order requires LG&E and KU to file a CPCN prior to constructing Phases 2 and 3 at the Ghent landfill and Phases 2 through 4 at the Trimble County landfill. The order also requires LG&E and KU to submit status update reports every three months on Phase 1 of Trimble County landfill. Phase 1 of construction at Trimble County will commence after the required state permits are obtained. Phase 1 of the Ghent landfill was completed in December 2014. CPCN and ECR Filings On January 29 , 2016, LG&E and KU s ubmit ted application s to the KPSC for CPCNs and for ECR rate treatment regarding upcoming environmental construction projects relating to the EPA's regulations addressing the handling of coal combu stion byproducts and MATS . The construction projects are expected to begin in 2016 and continue through 2023 and are estimated to cost approximately $316 million at LG&E and $678 million at KU. The applications request an authorized 10% return on equity with respect to LG&E and KU's ECR mechanism consistent with the 2014 Kentucky rate case approved in June 2015. Pennsylvania Activities (PPL and PPL Electric) Act 11 authorizes the PUC to approve two specific ratemaking mechanisms: the use of a fully projected future test year in base rate proceedings and, subject to certain conditions, the use of a DSIC. Such alternative ratemaking procedures and mechanisms provide opportunity for accelerated cost- recovery and, therefore, are important to PPL Electric as it is in a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging distribution assets Rate Case Proceeding On M arch 31, 2015, PPL Electric filed a request with the PUC for an increase in its annual distribution revenue requirement of approximately $167.5 million. The application was based on a fully projected future test year of January 1, 2016 through December 31 , 2016. On September 3, 2015, PPL Electric filed with the PUC Administrative Law Judge a petition for approval of a settlement agreement under which PPL Electric would be permitted to increase its annual distribution rates by $124 million, effective Janua ry 1, 2016. On November 19, 2015, the PUC entere d a final order adopting the Administrative Law Judge’s recommended decision. The new rates became effective January 1, 2016. Distribution System Improvement Charge (DSIC) On March 31, 2015, PPL Electric filed a petition requesting a waiver of the DSIC cap of 5% of billed revenues and approval to increase the maximum allowable DSIC from 5% to 7.5% for service rendered after January 1, 2016. PPL Electric filed the petition concurrently with its 2015 rate c ase and the Administrative Law Judge granted PPL Electric's request to consolidate these two proceedings. Under the terms of the settlement agreement discussed above, PPL Electric agreed to withdraw the petition without prejudice to re-file it at a later date. In September 2012, PPL Electric filed its LTIIP describing projects eligible for inclusion in the DSIC and, in an order entered on May 23, 2013, the PUC approved PPL Electric's proposed DSIC with an initial rate effective July 1, 2013, subject to re fund after hearings. The PUC also assigned four technical recovery calculation issues to the Office of Administrative Law Judge for hearing and preparation of a recommended decision. In November 2015, the PUC issued an opinion and order approving PPL Ele ctric’s Petition with minor modifications. Storm Damage Expense Rider (SDER) In its December 2012 final rate case order, the PUC directed PPL Electric to file a proposed SDER. The SDER is a reconcilable automatic adjustment clause under which PPL Elect ric annually will compare actual storm costs to storm costs allowed in base rates and refund or recoup any differences from customers. In March 2013, PPL Electric filed its proposed SDER with the PUC and, as part of that filing, requested recovery of the 2012 qualifying storm costs related to Hurricane Sandy. PPL Electric proposed that the SDER become effective January 1, 2013 at a zero rate with qualifying storm costs incurred in 2013 and the 2012 Hurricane Sandy costs be included in rates effective Janu ary 1, 2014. In April 2014, the PUC issued a final order approving the SDER with a January 1, 2015 effective date and initially including actual storm costs compared to collections for December 2013 through November 2014. As a result, PPL Electric reduce d its regulatory liability by $12 million in March 2014. Also, as part of the April 2014 order, PPL Electric was authorized to recover Hurricane Sandy storm damage costs through the SDER of $29 million over a three-year period beginning January 1, 2015. In June 2014, the Office of Consumer Advocate (OCA) filed a petition with the Commonwealth Court of Pennsylvania requesting that the Court reverse and remand the April 2014 order permitting PPL Electric to establish the SDER. In December 2015, the Common wealth Court issued an Opinion affirming the PUC’s April 2014 Order. On January 15, 2015, the PUC issued a final order closing an investigation related to a separate OCA complaint concerning PPL Electric's October 2014 preliminary SDER calculation and mod ified the effective date of the SDER to February 1, 2015. In the PUC rate case settlement agreement approved by the Commission in November 2015, it was determined that reportable storm damage expenses to be recovered annually through

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2015
Financing Activities [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 P PL 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: December 31, 2015 December 31, 2014 Letters of Letters of Credit Credit and and Commercial Commercial Expiration Paper Unused Paper Date Capacity Borrowed Issued Capacity Borrowed Issued PPL U.K. WPD plc Syndicated Credit Facility (a) (c) Dec. 2016 £ 210 £ 133 £ 77 £ 103 WPD (South West) Syndicated Credit Facility (a) (c) July 2020 245 245 WPD (East Midlands) Syndicated Credit Facility (a) (c) July 2020 300 300 64 WPD (West Midlands) Syndicated Credit Facility (a) (c) July 2020 300 300 Uncommitted Credit Facilities 40 £ 4 36 £ 5 Total U.K. Credit Facilities (b) £ 1,095 £ 133 £ 4 £ 958 £ 167 £ 5 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Nov. 2018 $ 300 $ 151 $ 149 Syndicated Credit Facility (c) (d) July 2019 300 300 Bilateral Credit Facility (c) (d) Mar. 2016 150 20 130 $ 21 Total PPL Capital Funding Credit Facilities $ 750 $ 471 $ 279 $ 21 PPL Electric Syndicated Credit Facility (c) (d) July 2019 $ 300 $ 1 $ 299 $ 1 LKE Syndicated Credit Facility (c) (d) (f) Oct. 2018 $ 75 $ 75 $ 75 LG&E Syndicated Credit Facility (c) (d) July 2019 $ 500 $ 142 $ 358 $ 264 KU Syndicated Credit Facility (c) (d) July 2019 $ 400 $ 48 $ 352 $ 236 Letter of Credit Facility (c) (d) (e) Oct. 2017 198 198 198 Total KU Credit Facilities $ 598 $ 246 $ 352 $ 434 (a ) The facilities contain financial covenants to maintain an interest coverage ratio of not less than 3.0 times consolidated earnings before income taxes, depreciation and amortization and total net debt not in excess of 85% of its RAV, calculated in accordance with the credit facility. (b) WPD plc's amounts borrowed at December 31, 2015 and 2014 were USD-denominated borrowings of $ 200 million and $ 161 million, which bore interest at 1.83% and 1.86% . WPD (East Midlands) amount borrowed at December 31, 2014 was a GBP-denominated borrowing which equated to $ 100 million and bore interest at 1.00% . At December 31, 2015 , the unused capacity under the U.K. credit facilities was approximately $ 1.4 billion . ( c ) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin. (d) The facilities contain a financial covenant requiring debt to total capitalizati on not to exceed 70% for PPL Capital Funding, PPL Electric, LKE, LG&E and KU, as calculated in accordance with the facilities and other customary covenants . Additionally, as it relates to the syndicated and bilateral cre dit facilities and subject to certain conditions, PPL Capital Funding may request that the capacity of its facility expiring in July 2019 be increased by up to $ 100 million and the facilities expiring in November 2018 and March 2016 may be increased by up to $ 30 million, PPL Electric, LG&E and KU each may request up to a $ 100 million increase in its fac ility's capacity and LKE may request up to a $ 25 million increase in its facility's capacity. (e) KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted t o loans rather than requiring immediate payment. (f) At December 31, 2015 , LKE's interest rate on outstanding borrowings was 1.68% . At December 31, 2014 , LKE’s interest rate on outstanding borrowings was 1.67% . In January 2016, WPD plc replaced its existing syndicated credit facility expiring in December 2016 with a new £ 210 million facility expiring in January 2021 . In January 2016, the expirati on dates for the PPL Capital Funding and PPL Electric syndicated credit facilities expiring in July 2019 were extended to January 2021 . PPL Capital Funding's capacity was increased to $ 700 million and PPL Electric's capacity was increased to $ 400 million. The expiration dates for the LG&E and KU syndicated credit facilities expiring in July 2019 were extended to December 2020 . Additionally, subject to certain conditions, PPL Capital Funding and PPL El ectric may each request up to a $ 250 million increase in its facility's capacity and LG&E and KU may each request up to a $ 100 million increase to the capacities of their facilities. PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquid ity 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 a t: December 31, 2015 December 31, 2014 Weighted - Commercial Weighted - Commercial Average Paper Unused Average Paper Interest Rate Capacity Issuances Capacity Interest Rate Issuances PPL Capital Funding 0.78% $ 600 $ 451 $ 149 PPL Electric 300 300 LG&E 0.71% 350 142 208 0.42% $ 264 KU 0.72% 350 48 302 0.49% 236 Total $ 1,600 $ 641 $ 959 $ 500 ( PPL and LKE ) See Note 14 for discussion of intercompany borrowings. Long-term Debt ( All Registrants ) Weighted-Average December 31, Rate (g) Maturities (g) 2015 2014 PPL U.S. Senior Unsecured Notes 3.87% 2018 - 2044 $ 3,425 $ 3,825 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.97% 2016 - 2045 6,874 6,074 Junior Subordinated Notes 6.31% 2067 - 2073 930 930 Total U.S. Long-term Debt 11,229 10,829 U.K. Senior Unsecured Notes (d) 5.33% 2016 - 2040 7,170 6,627 Index-linked Senior Unsecured Notes (e) 1.82% 2043 - 2056 772 732 Total U.K. Long-term Debt (f) 7,942 7,359 Total Long-term Debt Before Adjustments 19,171 18,188 Fair market value adjustments 30 37 Unamortized premium and (discount), net (e) (28) (52) Unamortized debt issuance costs (125) (119) Total Long-term Debt 19,048 18,054 Less current portion of Long-term Debt 485 1,000 Total Long-term Debt, noncurrent $ 18,563 $ 17,054 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.50% 2020 - 2045 $ 2,864 $ 2,614 Total Long-term Debt Before Adjustments 2,864 2,614 Unamortized discount (13) (12) Unamortized debt issuance costs (23) (21) Total Long-term Debt 2,828 2,581 Less current portion of Long-term Debt 100 Total Long-term Debt, noncurrent $ 2,828 $ 2,481 LKE Senior Unsecured Notes 3.97% 2020 - 2021 $ 725 $ 1,125 First Mortgage Bonds (a) (c) 3.58% 2016 - 2045 4,010 3,460 Long-term debt to affiliate 3.50% 2025 400 Total Long-term Debt Before Adjustments 5,135 4,585 Fair market value adjustments (1) (1) Unamortized discount (16) (17) Unamortized debt issuance costs (30) (24) Total Long-term Debt 5,088 4,543 Less current portion of Long-term Debt 25 900 Total Long-term Debt, noncurrent $ 5,063 $ 3,643 LG&E First Mortgage Bonds (a) (c) 3.36% 2016 - 2045 $ 1,659 $ 1,359 Total Long-term Debt Before Adjustments 1,659 1,359 Fair market value adjustments (1) (1) Unamortized discount (4) (5) Unamortized debt issuance costs (12) (8) Total Long-term Debt 1,642 1,345 Less current portion of Long-term Debt 25 250 Total Long-term Debt, noncurrent $ 1,617 $ 1,095 KU First Mortgage Bonds (a) (c) 3.74% 2020 - 2045 $ 2,351 $ 2,101 Total Long-term Debt Before Adjustments 2,351 2,101 Unamortized discount (10) (10) Unamortized debt issuance costs (15) (12) Total Long-term Debt 2,326 2,079 Less current portion of Long-term Debt 250 Total Long-term Debt, noncurrent $ 2,326 $ 1,829 (a ) Includ e s PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric 's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $ 6.7 billion and $ 5.8 billion at December 31, 2015 and 2014 . Includes LG&E's first m ortgage bonds that are secured by the lien of t he LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $ 4.2 billion and $ 3.7 billion at December 31, 2015 and 2014 . Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substan tially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $ 5.7 billion and $ 5.5 billion at December 31, 2015 and 2014 . (b ) Includes PPL Electric 's series of senior secured bonds that secure its obligations to make payments with respect to each se ries of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same inte rest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indentur e and are secured as noted in (a ) above. This amount includes $ 224 million that may be rede emed at par beginning in 2015 and $ 90 million that may be redeemed, in whole or in part, at par beginning in October 2020 and are subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes. (c) Includes LG&E 's and KU 's series of first mortgage bonds that were issued to the respective trustee s of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amount s , contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in ( a ) above. The related tax-exempt revenue bonds wer e issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate . At December 31, 2015 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $ 418 million for LKE, comprised of $ 391 million and $ 27 million for LG&E and KU , respectively . At December 31, 2015 , the aggregate tax-exempt revenue bonds issued on be half of LG&E and KU that were in a variable rate mode totaled $ 507 million for LKE, comprised of $ 183 million and $ 324 million for LG&E and KU , respectively . Several series of the tax-exempt revenue bonds are insured by monoline bond insurers whose ratings were reduced due to exposures relating to insurance of sub-prime mortgages. Of the bonds outstanding, $ 231 million are in the form of insured auction rate securities ($ 135 million for LG&E and $ 96 million for KU) , wherein interest rates are reset either weekly or every 35 days via an auction proces s. Beginning in late 2007, the interest rates on these insured bonds began to increase due to investor concerns about the creditworthiness of the bond insurers. During 2008, interest rates increased, and LG&E and KU experienced failed auctions when there were insufficient bids for the bonds. When a failed auction occurs, the interest rate is set pursuant to a formula stipulated in the indenture. As noted above, the instruments governing these auction rate bonds permit LG&E and KU to convert the bonds to other interest rate modes. Certain of the variable rate tax-exempt revenue bonds totaling $ 251 million at December 31, 2015 ($ 23 million for LG&E and $ 228 million for KU) , are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events. ( d ) I ncludes £ 225 million ($ 339 million at December 31, 2015 ) of notes that may be redeemed, in total but not in part, on December 21, 2026 , at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. G overnment bond. ( e ) The principal amount of the notes issued by WPD (South West) and WPD (East Midlands) is adjusted based on changes in a specified index, as detailed in the terms of the related indentures. The adjustment to the princi pal amount s from 2014 to 2015 was an increase of approximately £ 4 million ($ 6 million) resulting from inflation . In addition, this amount includes £ 225 million ($ 339 million at Decembe r 31, 2015 ) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026 , at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nomina ted U.K. government bond. (f) I ncludes £ 4.4 billion ($ 6.6 billion at December 31, 2015 ) of notes tha t may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the n otes are withdrawn by any of the rating agencies (Moody's or S&P) or reduced to a non-investment grade rating of Ba1 or BB+ or lower in connection with a restructu ring event which includes the loss of, or a material adverse change to, the distribution license s under which the issuer operate s . (g) The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2015 . None of the outstanding debt securities noted above have sinking fund requirements. The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2016 through 2020 and thereafter are as follows: PPL PPL Electric LKE LG&E KU 2016 $ 485 $ 25 $ 25 2017 294 194 194 2018 348 98 98 2019 40 40 40 2020 1,301 $ 100 975 $ 500 Thereafter 16,703 2,764 3,803 1,302 1,851 Total $ 19,171 $ 2,864 $ 5,135 $ 1,659 $ 2,351 (PPL) In May 2013, PPL Capital Funding remarketed $ 1.150 billion of 4.625% Junior Subordinated Notes due 2018 that were originally issued in June 2010 as a component of PPL's 2010 Equity Units. In connection with the remarketing, PPL Capital Funding issued $ 300 million of 2.04% Junior Subordinated Notes due 2016 and $ 850 million of 2.77% Junior Subordinated Notes due 2018 , which were simultaneously exchanged fo r three tranches of Senior Notes: $ 250 million of 1.90% Senior Notes due 2018 , $ 600 million of 3.40% Senior Notes due 2023 and $ 300 million of 4.70% Senior Notes due 2043 . The transaction was accounted for as a debt extinguishment, resulting in a $ 10 million loss on extinguishment of the Junior Subordinated Notes, recorded to "Interest Expense" on the S tatement of Income. The transaction was considered non-cash activity that was excluded from the Statement of Cash Flows for the year ended December 31, 2013 . Additionally, in July 2013, PPL issued 40 million shares of common stock at $ 28.73 per share to settle the 2010 Purchase Contracts. PPL received net cash proceeds of $ 1.150 billion, which were used to repay short-term and long-term debt and for general corporate purposes. In March 2014, PPL Capital Funding remarketed $ 978 million of 4.32% Junior Subordinated Notes due 2019 that were ori ginally issued in April 2011 as a component of PPL's 2011 Equity Units. In connection with the remarketing, PPL Capital Funding retired $ 228 million of the 4.32% Junior Subordinate d Notes due 2019 and issued $ 350 million of 2.189% Junior Subordinated Notes due 2017 and $ 400 million of 3.184% Junior Subordinated Notes due 2019 . Simultaneously, the newly issued Junior Subordinated Notes were exchanged for $ 350 million of 3.95% Senior Notes due 2024 and $ 400 million of 5.00% Senior Notes due 2044 . The transaction was accounted for as a debt extinguishment, resulting in a $ 9 million loss on extinguishment of the Junior Subordinated Notes, recorded to "Interest Expense" on the Statement of Income. Except for the $ 228 million retirement of the 4.32% Junior Subordinated Notes and fees related to the transactions, the activity was non-cash and excluded from the Statement of Cash Flows for the year ended December 31, 2014. Additionally, in May 2014, PPL issued 31.7 million shares of common stock at $ 30.86 per share to settle the 2011 Purchase Contracts. PPL received net cash proceeds of $ 978 million, which were used to repay short-term debt and for general corporate purposes. In November 2015, WPD p lc issued £ 500 million aggregate nominal value of 3.625% Notes due 2023 . WPD plc received proceeds of £ 495 million, which equated to $ 746 million at the time of issuance, net of a discount a nd underwriting fees, which will be used for general corporate purposes, including the re-financing of existing debt. (PPL and PPL Electric) In October 2015, PPL Electric issued $ 350 million of 4.15% First Mortgage Bonds due 2045 . PPL Electric received proceeds of $ 345 million, net of a discount and underwriting fees, which were used to repay short-term debt and for general corporate purposes. In December 2015, PPL Electric repaid the entire $ 100 million principal amount of its 4.95% Senior Secured Bonds upon maturity. (PPL, LKE and LG&E) In September 2015, LG&E issued $ 300 million of 3.30% First Mortgage Bonds due 2025 and $ 250 million of 4.375% First Mortgage Bonds due 2045 . LG&E received proceeds of $ 298 million and $ 248 million, net of discounts and underwriting fees, which were used to repay short-term debt, to repay 1.625% First Mortgage Bonds that matured in November 2015 and for general corporate purposes. (PPL, LKE and KU) In September 2015, KU issued $ 250 million of 3.30% First Mortgage Bonds due 2025 and $ 250 million of 4.375% First Mortgage Bonds due 2045 . KU received proceeds of $ 248 million for each issuance, net of discounts and underwriting fees, which were used to repay short-term debt, to repay 1.625% First M ortgage Bonds that matured in November 2015 and for general corporate purposes. (PPL and LKE) In November 2015, LKE borrowed $400 million from a PPL affiliate through the issuance of a 3.50% note payable due 2025. The proceeds were used to repay the entire $400 million principal amount of its 2.125% Senior Unsecured Notes which matured in November 2015. See Note 14 for more information related to intercompany borrowings. Legal Separateness ( All Registrants ) The subsidiaries of PPL are separate le gal entities. PPL's subsidiaries are not liable for the debts of PPL. Accordingly, creditors of PPL may not satisfy their debts from the assets of PPL’s subsidiaries absent a specific contractual undertaking by a subsidiary to pay PPL's creditors or as r equired by applicable law or regulation. Similarly, PPL is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of PPL's subsidiaries may not satisfy their debts from the asset s of PPL or its other subsidiaries absent a specific contractual undertaking by PPL or its other subsidiaries to pay the creditors or as required by applicable law or regulation. Similarly, the subsidiaries of PPL Electric and LKE are each separate legal entities. These subsidiaries are not liable for the debts of PPL Electric and LKE. Accordingly, creditors of PPL Electric and LKE may not satisfy their debts from the assets of their subsidiaries absent a specific contractual undertaking by a subsidiary to pay the creditors or as required by applicable law or regulation. Similarly, PPL Electric and LKE are not liable for the debts of their subsidiaries, nor are their subsidiaries liable for the debts of one another. Accordingly, creditors of these subsi diaries may not satisfy their debts from the assets of PPL Electric and LKE (or their other subsidiaries) absent a specific contractual undertaking by that parent or other subsidiary to pay such creditors or as required by applicable law or regulation. (PPL) A T M 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. During 2015 , PPL issued 1,476,700 shares of common stock under the program at an average price of $ 33.41 per share, receiving net proceeds of $ 49 million. Distributions and Related Restrictions In November 2015 , PPL declared its quarterly common stock dividend, payable January 4 , 2016 , at 37.75 cents per share (equivalent to $ 1.51 per annum). On February 4, 2016, PPL anno unced that the company is increasing its common stock dividend to 38 cents per share on a quarterly basis (equivalent to $ 1.52 per annum). Future dividends, declared at the discretion of the Board of Directors, will depend up on future earnings, cash flows, financial and legal requirements and other factors. See Note 8 for information regarding the June 1, 2015 distribution to PPL’s shareowners of a newly formed entity, Holdco, which at closing owned all of the membership interests of PPL Energy Supply and all of the common stock of Talen Energy. Neither PPL Capital Funding nor PPL may declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest paymen ts on its 2007 Series A Junior Subordinated Notes due 2067 or 2013 Series B Junior Subordinated Notes due 2073. At December 31, 2015 , no interest payments were deferred . WPD subsidiaries have financing arrangements that limit their ability to pay dividends . However, PPL does not, at this time, expect that any of such limitations would significantly impact PPL's ability to meet its cash obligations. ( All Registrants ) PPL relies on dividends or loans from its subsidiaries to fund P PL's dividends to its common shareholders. The net assets of certain PPL subsidiaries are subject to legal restrictions. LKE primarily relies on dividends from its subsidiaries to fund its distributions to PPL. LG&E, KU and PPL Electric are subject to S ection 305(a) of the Federal Power Act, which makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in capital account." The meaning of this limitation has never been clarified under the Federal Power Act. LG& E, KU and PPL Electric believe, however, that this statutory restriction, as applied to their circumstances, would not be construed or applied by the FERC to prohibit the payment from retained earnings of dividends that are not excessive and are for lawful and legitimate business purposes. In February 2012, LG&E and KU petitioned the FERC requesting authorization to pay dividends in the future based on retained earnings balances calculated without giving effect to the impact of purchase accounting adjustme nts for the acquisition of LKE by PPL. In May 2012, FERC approved the petitions with the further condition that each utility may not pay dividends if such payment would cause its adjusted equity ratio to fall below 30% of total capitalization. Accordingly, at December 31, 2015 , net assets of $ 2.7 billion ($ 1.1 billion for LG&E and $ 1.6 billion for KU) were restricted for purpo ses of paying dividends to LKE, and net assets of $ 2.9 billion ($ 1.2 billion for LG&E and $ 1.7 billion for KU) were available for payment of dividends to LKE. L G&E and KU believe they will not be required to change their current dividend practices as a result of the foregoing requirement. In addition, under Virginia law, KU is prohibited from making loans to affiliates without the prior approval of the VSCC. Th ere are no comparable statutes under Kentucky law applicable to LG&E and KU, or under Pennsylvania law applicable to PPL Electric. However, orders from the KPSC require LG&E and KU to obtain prior consent or approval before lending amounts to PPL.

Acquisitions, Development and D

Acquisitions, Development and Divestitures	12 Months Ended
	Dec. 31, 2015
Acquisitions Development And Divestitures [Abstract]
Acquisitions, Development and Divestitures	8. Acquisitions, Development and Divestitures ( All Registrants ) The Registrants from time to time evaluate opportunities for potential acquisitions, divestitures and development projects. Development projects are reexamined based on market conditions and other factors to determine whether to proceed with, modify or terminate the projects. Any resulting transactions may impact future financial results. (PPL) Discontinued Operations Spinoff of PPL Energy Supply In June 2014, PPL and PPL Energy Supply executed definitive agreements with affiliates of Riverstone to spin off PPL Energy Supply and immediately combine it with Riverstone’s competitive power generation businesses to form a new, stand-alone, publicly traded company named Talen Energy. The transaction was subject to customary closing conditions, including receipt of regulatory approvals from the NRC, FERC, DOJ and PUC, all of which were received by mid-April 2015. On April 29, 2015, PPL’s Board of Directors declared the June 1, 2015 distribution to PPL’s shareowners of record on May 20, 2015 of a newly formed entity, Holdco, which at closing owned all of the membership intere sts of PPL Energy Supply and all of the common stock of Talen Energy. Immediately following the spinoff on June 1, 2015, Holdco merged with a special purpose subsidiary of Talen Energy, with Holdco continuing as the surviving company to the merger and as a wholly owned subsidiary of Talen Energy and the sole owner of PPL Energy Supply. Substantially contemporaneous with the spinoff and merger, RJS Power was contributed by its owners to become a subsidiary of Talen Energy. PPL shareowners received approxi mately 0.1249 shares of Talen Energy common stock for each share of PPL common stock they owned on May 20, 2015. Following completion of these transactions, PPL shareowners owned 65% of Talen Energy and affil iates of Riverstone owned 35% . The spinoff had no effect on the number of PPL common shares owned by PPL shareowners or the number of shares of PPL common stock outstanding. The transaction is intended to be tax-free to PPL and its shareowners for U.S. federal income tax purposes. PPL has no continuing ownership interest in, control of, or affiliation with Talen Energy and Talen Energy Supply (formerly PPL Energy Supply). Loss on Spinoff In conjunction with the accounti ng for the spinoff, PPL evaluated whether the fair value of the Supply segment’s net assets was less than the carrying value as of the June 1, 2015 spinoff date. PPL considered several valuation methodologies to derive a fair value estimate of its Supply segment at the spinoff date. These methodologies included considering the closing “when-issued” Talen Energy market value on June 1, 2015 (the spinoff date), adjusted for the proportional share of the equity value attributable to the Supply segment, as we ll as, the valuation methods consistently used in PPL’s goodwill impairment assessments – an income approach using a discounted cash flow analysis of the Supply segment and an alternative market approach considering market multiples of comparable companies . Although the market value of Talen Energy approach utilized the most observable inputs of the three approaches, PPL considered certain limitations of the “when-issued” trading market for the spinoff transaction including the short trading duratio n, lack of liquidity in the market and anticipated initial Talen stock ownership base selling pressure, among other factors, and concluded that these factors limit the appropriateness of this input being solely determinative of the fair value of the Supply segment. As such, PPL also considered the other valuation approaches in estimating the overall fair value, but ultimately assigned the highest weighting to the Talen Energy market value approach. The following table summarizes PPL's fair value analys is: Weighted Fair Value Approach Weighting (in billions) Talen Energy Market Value 50% $ 1.4 Income/Discounted Cash Flow 30% 1.1 Alternative Market (Comparable Company) 20% 0.7 Estimated Fair Value $ 3.2 A key assumption included in the fair value estimate is the application of a control premium of 25% in the two market approaches. PPL concluded it was appropriate to apply a control premium in these approaches as the goodwill impairment testing guidance was followed in determining the estimated fair value of the Supply segment, which had historically been a repor ting unit for PPL. This guidance provides that the market price of an individual security (and thus the market capitalization of a reporting unit with publically traded equity securities) may not be representative of the fair value of the reporting unit. This guidance also indicates that substantial value may arise to a controlling shareholder from the ability to take advantage of synergies and other benefits that arise from control over another entity, and that the market price of a Company’s individual share of stock does not reflect this additional value to a controlling shareholder. Therefore, the quoted market price need not be the sole measurement basis for determining the fair value, and including a control premium is appropriate in measuring the f air value of a reporting unit. In determining the control premium, PPL reviewed premiums received during the last five years in market sales transactions obtained from observable independent power producer and hybrid utility transactions gre ater than $ 1 billion. Premiums for these transactions ranged from 5% to 42% with a median of approximately 25% . Given these metrics, PPL concluded a control premium of 25% to be reasonable for both of the market valuation approaches used. Assumptions used in the discounted cash flow analysis included forward energy prices, forecasted generation, and forecasted operation and maintenance expenditures that were consiste nt with assumptions used in the Energy Supply portion of the recent Talen Energy business planning process and a market participant discount rate. Using these methodologies and weightings, PPL determined the estimated fair value of the Supply segment (c lassified as Level 3) was below its carrying value of $ 4.1 billion and recorded a loss on the spinoff of $ 879 million in the second quarter of 2015, which is reflected in discontinued operations and is nondeductible for tax purposes . This amount served to reduce the basis of the net assets accounted for as a dividend at the June 1, 2015 spinoff date. Costs of Spinoff Following the announcement of the transaction to form Talen Energy, efforts were initiated to identify the appropri ate staffing for Talen Energy and for PPL and its subsidiaries following completion of the spinoff. Organizational plans were substantially completed in 2014. The new organizational plans identified the need to resize and restructure the organizations an d as a result, in 2014, estimated charges of $ 36 million for employee separation benefits were recorded related to 306 positions. Of this amount, $ 16 million related to 112 Energy Supply positions and is reflected in discontinued operations. The remaining $ 20 million is primarily reflected in "Other operation and maintenance" on the PPL Consolidated Statements of Income. In 2015, the organizational structures were finalized for both PPL and Talen Energy which resulted in an additional charge of $ 10 million for employee separation benefits. Of this amount, $ 2 million related to Energy Supply positions and is reflected in discontinued operations. The r emaining $ 8 million is reflected in "Other operation and maintenance" on the PPL Consolidated Statements of Income. The separation benefits include cash severance compensation, lump sum COBRA reimbursement payments and outplacement servic es. At December 31, 2015 and 2014, the recorded liabilities related to the separation benefits were $ 13 million and $ 20 million, which are included in “Other current liabilities” on the Balan ce Sheets. Additional employee-related costs incurred primarily included accelerated stock-based compensation and prorated performance-based cash incentive and stock-based compensation awards, primarily for PPL Energy Supply employees and for PPL Services employees who became PPL Energy Supply employees in connection with the transaction. PPL Energy Supply recognized $ 24 million of these costs at the spinoff closing date in 2015, which are reflected in discontinued operations. As the vesting for all PPL Energy Supply employees was accelerated and all remaining unrecognized compensation expense accelerated concurrently with the spinoff, PPL does not expect to recognize significant future compensation costs for equity awards held by former PPL Energy Supply employees. PPL’s future stock-based compensation expense will not be significantly impacted by equity award adjustments that occurred as a result of the spinoff. Stock-based compensation expense recognized in future periods f or PPL's outstanding awards will correspond to the unrecognized compensation expense as of the date of the spinoff, which reflects the unamortized balance of the original grant date fair value of the equity awards held by PPL employees. PPL recorded $ 45 million and $ 27 million of third-party costs related to this transaction in 2015 and 2014. Of these costs, $ 32 million and $ 19 million were primarily for bank advisory, legal and accounting fees to facilitate the transaction, and are reflected in discontinued operations. An additional $ 13 million and $ 8 million of consulting and other costs were incurred in 2015 and 2014, related to the formation of the Talen Energy organization and to reconfigure the remaining PPL service functions. These costs are recorded pr imarily in "Other operation and maintenance" on the Statements of Income. No significant additional third-party costs are expected to be incurred. At the close of the transaction in 2015, $ 72 million ($ 42 millio n after-tax) of cash flow hedges, primarily unamortized losses on PPL interest rate swaps recorded in AOCI and designated as cash flow hedges of PPL Energy Supply’s future interest payments, were reclassified into interest expense and reflected in discontinued ope rations. As a result of the June 2014 spinoff announcement, PPL recorded $ 50 million of deferred income tax expense in 2014, to adjust valuation allowances on deferred tax assets primarily for state net operating loss carryforwards that were previously supported by the future earnings of PPL Energy Supply. Continuing Involvement (PPL and PPL Electric) As a result of the spinoff, PPL and PPL Energy Supply entered into a Transition Services Agreement (TSA) that terminates no later than two years from the spinoff date . The TSA sets forth the terms and conditions for PPL and Talen Energy to provide certain transition services to one another. PPL will provide Talen Energy certain information technology, financial and accounti ng, human resource and other specified services. In 2015, PPL billed $ 25 million to Talen Energy for these services. In general, the fees for the transition services allow the provider to recover its cost of the services, including overheads, but without margin or profit. Additionally, prior to the spinoff, through the annual competitive solicitation process, PPL EnergyPlus was awarded supply contracts for a portion of the PLR generation supply for PPL Electric, which were retained by Talen Ene rgy Marketing as part of the spinoff transaction. PPL Electric's supply contracts with Talen Energy Marketing extend through November 2016. The energy purchases were previously included in PPL Electric's Statements of Income as "Energy purchases from aff iliate" but were eliminated in PPL’s Consolidated Statements of Income. Subsequent to the spinoff, PPL Electric’s energy purchases from Talen Energy Marketing were $ 27 million and are no longer considered affiliate transactions. (PPL) Summarized Results of Discontinued Operations The operations of the Supply segment are included in “Income (Loss) from Discontinued Operations (net of income taxes)” on the Statements of Income. Following are the components of Discontinued Operations in the Statements of Income for the periods ended December 31: 2015 2014 2013 Operating revenues $ 1,427 $ 3,848 $ 4,648 Operating expenses 1,328 3,410 4,173 Other Income (Expense) - net (21) 13 32 Interest expense (a) 150 190 228 Gain on sale of Montana Hydro Sale 237 Loss on lease termination (697) Income tax expense (benefit) (30) 198 (180) Loss on spinoff (879) Income (Loss) from Discontinued Operations (net of income taxes) $ (921) $ 300 $ (238) (a) Includes interest associated with the Supply segment with no additional allocation as the Supply segment was sufficiently capitalized. Summarized Assets and Liabilities of Discontinued Operations The assets and liabilities of PPL’s Supply segment for all periods prior to the spinoff are included in “Current assets of discontinued operations”, “Noncurrent assets of discontinued operations”, “Current liabilities of discontinued operations” and “Noncurrent liabilities of discontinued operations” on P PL’s Balance Sheet. Net assets, after recognition of the loss on spinoff, of $ 3.2 billion were distributed to PPL shareowners in the June 1, 2015, spinoff of PPL Energy Supply. The following major classes of assets and liabilities were dis tributed and removed from PPL's Balance Sheet on June 1, 2015. Additionally, the following major classes of assets and liabilities were reclassified to discontinued operations as of December 31, 2014: Discontinued Distribution on Operations at June 1, December 31, 2015 2014 Cash and cash equivalents (a) $ 371 $ 352 Restricted cash and cash equivalents 156 176 Accounts receivable and unbilled revenues 334 504 Fuels, materials and supplies 415 455 Price risk management assets 784 1,079 Other current assets 46 26 Total Current Assets 2,106 2,592 Investments 999 980 PP&E, net 6,384 6,428 Goodwill 338 338 Other intangibles 260 257 Price risk management assets 244 239 Other noncurrent assets 63 69 Total Noncurrent Assets 8,288 8,311 Total assets $ 10,394 $ 10,903 Short-term debt and long-term debt due within one year $ 885 $ 1,165 Accounts payable 252 361 Price risk management liabilities 763 1,024 Other current liabilities 229 221 Total Current Liabilities 2,129 2,771 Long-term debt (excluding current portion) 1,917 1,677 Deferred income taxes 1,246 1,219 Price risk management liabilities 206 193 Accrued pension obligations 266 299 Asset retirement obligations 443 415 Other deferred credits and noncurrent liabilities 103 150 Total Noncurrent Liabilities 4,181 3,953 Total liabilities $ 6,310 $ 6,724 Adjustment for loss on spinoff 879 Net assets distributed $ 3,205 (a) The distribution of PPL Energy Supply’s cash and cash equivalents at June 1, 2015 is included in "Net cash provided by (used in) financing activities - discontinued operations" on the Statement of Cash Flows for the year ended December 31, 2015 . Montana Hydro Sale In November 2014, PPL Montana completed the sale to NorthWestern of 633 MW of hydroelectric generating facilities located in Montana for approximately $ 900 million in cash. The procee ds from the sale remained with PPL and did not transfer to Talen Energy as a result of the spinoff of PPL Energy Supply. The sale included 11 hydroelectric power facilities and related assets, included in the Supply segment. A gain of $ 237 million ($ 137 million after-tax) was recorded on the sale of the hydroelectric power facilities. In December 2013, to facilitate the sale of the Montana hydroelectric generating facilities, PPL Montana t erminated its operating lease arrangement related to partial interests in the Colstrip coal-fired electric generating facility and acquired those interests collectively for $ 271 million. A loss of $ 697 million ($ 413 million after-tax) was recorded for the termination of the lease arrangement. As the Montana hydroelectric power facilities were previously reported as a component of PPL Energy Supply and the Supply segment, the components of discontin ued operations for these facilities contained in the Statements of Income are included in the disclosure above. Development Regional Transmission Line Expansion Plan (PPL and PPL Electric ) Susquehanna-Roseland In 2007, PJM directed the construction of a new 150 -mile, 500 -kV transmission line between the Susquehanna substation in Pennsylvania and the Roseland substation in New Jersey that it identifi ed as essential to long-term reliability of the Mid-Atlantic electricity grid. PJM determined that the line was needed to prevent potential overloads that could occur on several existing transmission lines in the interconnected PJM system. PJM directed P PL Electric to construct the Pennsylvania portion of the Susquehanna-Roseland line and Public Service Electric & Gas Company to construct the New Jersey portion of the line . The line was energized, in May 2015. At December 31, 2015 and 2014 , $ 648 million and $ 597 million of costs were capitalized and are included on the Balance Sheet primarily in "Regulated utility plant" for 2015 and "Construction work in prog ress" for 2014 . Northeast/Pocono In October 2012, the FERC issued an order in response to PPL Electric's December 2011 request for ratemaking incentives for the Northeast/Pocono Reliability project (a new 58 -mile, 230 kV transmission line that includes three new substations and upgrades to adjacent facilities). The FERC granted the incentive for inclusion in rate base of all prudently incurred construc tion work in progress (CWIP) costs but denied the requested incentive for a 100 basis point adder to the return on equity. In December 2012, PPL Electric submitted an application to the PUC requesting permission to site and construct the project. In January 2014, the PUC issued a Final Order approving the application. PPL Electric expects the project to be completed in 2016. At December 31, 2015 , PPL Electric's estimated cost of the project was $ 335 million . At December 31, 2015 and 2014 , $ 319 million and $ 183 million of costs were capitalized and are included on the Balance Sheet primarily in "Regulated utility plant" for 2015 and "Constructi on work in progress" for 2014 . Capacity Needs (PPL, LKE, LG&E and KU) The Cane Run Unit 7 NGCC was put into commercial operation on June 19, 2015. As a result and to meet more stringent EPA regulations, LG&E retired one coal-fired generating unit at the Cane Run plant in March 2015 and retired the remaining two coal-fired generating units at the plant in June 2015. Additionally, KU retired the remaining two coal-fired generating units at the Green River plant on September 30, 2015. LG&E and KU incurred costs of $ 11 million and $ 6 million, respectively, directly related to these retirements including inventory write- downs and separation benefits. However, there were no gains or losses on the retirement of these units. See Note 6 for more information related to the regulatory recovery of the costs associated with the retirement of the Green River units. In Decemb er 2014, a final order was issued by the KPSC approving the request to construct a 10 MW solar generation facility at E.W. Brown. LG&E and KU began construction activities in the fourth quarter of 2015 and project the plant to be p laced into commercial operation by June 2016 at a cost of approximately $ 30 million.

Leases

Leases	12 Months Ended
	Dec. 31, 2015
Leases [Line Items]
Leases	9. Leases ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land , gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10 Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47
LG And E And KU Energy LLC [Member]
Leases [Line Items]
Leases	9. Leases ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land , gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10 Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47
Louisville Gas And Electric Co [Member]
Leases [Line Items]
Leases	9. Leases ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land , gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10 Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47
Kentucky Utilities Co [Member]
Leases [Line Items]
Leases	9. Leases ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries have entered into various agreements for the lease of office space, vehicles, land , gas storage and other equipment. Rent - Operating Leases Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10 Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2015
Stock-Based Compensation [Line Items]
Stock-Based Compensation	10. Stock-Based Compensation ( PPL, PPL Electric and LKE) In 2012, shareowners approved the SIP . This equity plan replaced the ICP and incorporated the following changes:  Eliminates the potential to pay dividend equivalents on stock options.  Eliminates the automatic lapse of restrictions on all equity awards in the event of a "potential" change in control and requires that a termination of employment occur in the event o f a change in control before restrictions lapse.  Changes the treatment of outstanding stock options upon retirement to limit the exercise period to the earlier of the end of the term ( ten years from grant ) or five years after retirement. To further align the executives’ interests with those of PPL shareowners, this plan provides that each restricted stock unit entitles the executive to accrue additional restricted st ock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units are deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awa rds granted under the ICP and the ICPKE are currently paid in cash when dividends are declared by PPL. Under the ICP, SIP and the ICPKE (together, the Plans), restricted shares of PPL common stock, rest ricted stock units, performance units and stock options may be granted to officers and other key employees of PPL , PPL Electric , LKE and other affiliated companies. Awards under the Plans are made by the Compensation, Governance and Nominating Committee ( CGNC) of the PPL Board of Directors, in the case of the ICP and SIP , and by the PPL Corporate Leadership Council ( CLC ), in the case of the ICPKE. The following table details the award limits under each of the Plans. Annual Grant Limit Annual Grant Limit Total As % of For Individual Participants - Total Plan Outstanding Annual Grant Performance Based Awards Award PPL Common Stock Limit For awards For awards Limit On First Day of Options denominated in denominated in Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) ICP (a) 15,769,431 2% 3,000,000 SIP 10,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2% 3,000,000 (a) Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP. Any portion of these award s that has not been granted may be carried over and used in any subsequent year. If any award lapses, is forfeited or the rights of the participant terminate, the shares of PPL common stock underlying such an award are again available for grant. Shares d elivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws. Res tricted Stock and Restricted Stock Units Restricted shares of PPL common stock are outstanding shares with full voting and dividend rights. Restricted stock awards are granted as a retention award for select key executives and vest when the recipient re aches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The Plans allow for the grant of restricted stock units. Restricted stock units are awards based on the fair value of PPL common stock on the date of grant . Actual PPL common shares will be issued upon completion of a restriction period, generally three years. The fair value of restricted stock and restricted stock units granted is recognized on a straight-l ine basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immedi ately upon the date of grant. Recipients of restricted stock units granted under the ICPKE may also be granted the right to receive dividend equivalents through the end of the restriction period or until the award is forfeited. Restricted stock a nd restricted stock units are subject to forfeiture or accelerated payout under the p lan provisions for termination, retirement, disability and death of employees. Restrictions lapse on r estricted stock and restricted stock units fully , in certain situati ons, as defined by each of the Plans. The weighted-average grant date fair value of restricted stock and restricted stock units granted w as : 2015 2014 2013 PPL $ 34.50 $ 31.50 $ 30.30 PPL Electric 34.41 31.81 30.55 LKE 34.89 30.98 30.00 Restricted stock and restricted stock unit activity for 2015 was : Weighted- Average Restricted Grant Date Fair Shares/Units Value Per Share PPL Nonvested, beginning of period 3,485,520 $ 30.07 Granted 1,028,009 34.50 Anti-dilution adjustments (a) 247,098 N/A Vested (3,055,205) 29.34 Forfeited (25,947) 30.70 Nonvested, end of period (b) 1,679,475 29.65 PPL Electric Nonvested, beginning of period 286,811 $ 30.04 Transfer between registrants (22,730) 29.56 Granted 75,213 34.41 Anti-dilution adjustments (a) 18,661 N/A Vested (127,507) 29.12 Forfeited (9,363) 30.51 Nonvested, end of period 221,085 29.48 LKE Nonvested, beginning of period 341,468 $ 29.76 Transfer between registrants 4,300 31.74 Granted 98,360 34.89 Anti-dilution adjustments (a) 24,587 N/A Vested (149,752) 28.55 Nonvested, end of period 318,963 29.65 (a ) Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans. (b) Excludes 1,226,193 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the spinoff, but for which distribution will not occur until the end of the original restriction period of the awards. Substantially all restricted stock and restricted stock unit a wards are expected to vest. The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was: 2015 2014 2013 PPL $ 28 $ 11 $ 12 PPL Electric 4 2 3 LKE 4 1 Performance Units Performance units are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on total shareowner return during a three -year performance period. At the end of the period, payout is determined by comparing PPL's performance to the total shareowner return of the companies included in the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that compri se the applicable index on which each years' awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance t hreshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of wheth er the performance goals have been achieved. Under the p lan provisions, performance units are subject to forfeiture upon termination of employment except for retirement, disability or death of an employee, in which case the total performance units remain outstanding and are eligible for vesting through the conclusion of the performance period. Beginning in 2014, t he fair value of performance units granted to retirement-eligible employees is recognized as compensation expense on a straight-line basis over a one-year period, the minimum vesting period required for an employee to be entitled to payout of the awards. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three -year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year. The fair value of performance units granted in 2013 and prior years is recognized as compensation expense on a straight-l ine basis over the three -year performance period . Performance units vest on a pro rata basis , in certain situations, as defined by each of the Plan s . The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the perfor mance unit . Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded b ased on events not likely to recur that had impacted PPL and the companies in the index group. PPL uses a mix of historic and implied volatility to value awards. The weighted-average assumptions used in the model were: 2015 2014 2013 Expected stock volatility 15.90% 15.80% 15.50% Expected life 3 years 3 years 3 years The weighted-average grant date fair value of performance units granted w as : 2015 2014 2013 PPL $ 36.76 $ 34.55 $ 34.15 PPL Electric 37.93 34.43 33.97 LKE 37.10 34.12 33.84 Performance unit activity for 2015 was: Weighted- Average Grant Performance Date Fair Value Units Per Share PPL Nonvested, beginning of period 1,171,716 $ 33.77 Granted 481,197 36.76 Anti-dilution adjustment (a) 90,251 N/A Vested (509,139) 32.12 Forfeited (240,485) 33.35 Nonvested, end of period (b) 993,540 33.09 PPL Electric Nonvested, beginning of period 59,615 $ 33.77 Transfer between registrants (3,676) 35.80 Granted 21,798 37.93 Anti-dilution adjustment (a) 4,627 N/A Vested (8,497) 31.38 Forfeited (6,196) 31.38 Nonvested, end of period 67,671 33.05 LKE Nonvested, beginning of period 173,946 $ 33.32 Granted 66,439 37.10 Anti-dilution adjustment (a) 13,207 N/A Vested (30,921) 31.35 Forfeited (29,507) 31.36 Nonvested, end of period 193,164 32.96 (a) Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans. (b) Excludes 322,429 performance units for which the service vesting requirement was waived for former PPL Energy Supply employees as a result of the spinoff, but for which the ultimate number of shares to be distributed will depend on the actual attainment of the performance goals at the end of the specified perfor mance periods. The total fair value of performance units vesting for the year ended December 31, 2015 and 2014 was $6 million and $5 million for PPL and insignificant for PPL Electric and LKE. Stock Options PPL’s CGNC e liminated the use of stock options and changed its long-term incentive mix to 60% performance units and 40% performance-contingent restricted stock units, resulting in 100% performance-based long-term incentive mix for equity awards granted beginning in January 2014 . U nd er the Plans, stock options had been granted with an option exercise price per share not less than the fair value of PPL's common stock on the date of grant. Options outstanding at December 31, 2015 , become exercisable in equal installments over a three -year service period beginning one year after the date of grant, assuming the individual is still employed by PPL or a subsidiary . The CGNC and CLC have discretion to accelerate the exercisability of the options, except that the exercisability of an option issued under the ICP may not be accelerated unless the individual remains employed by PPL or a subsidiary for one year from the date of grant. All options expire no later than ten years from the grant date. The options become exercisable immediately in certain situations, as defined by each of the Plans. The fair value of options granted is recognized as compensation expense on a straight-line basis over the service period or through the date at whic h the employee reaches retirement eligibility. The fair value of options granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. The fair value of each option granted is estimated using a Black-Scholes option-pricing model. PPL uses a risk-free interest rate, expected option life, expected volatility and dividend yield to value its stock options. The risk-free interest rate reflects the yield for a U.S. Treasury Strip available on the date of grant with constant rate maturity approximating the option's expected life. Expected life is calculated based on historical exercise behavior. Volatility ov er the expected term of the options is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL 's volatility in those prior periods. Management's expectations for future vol atility, considering potential changes to PPL 's business model and other economic conditions, are also reviewed in addition to the historical data to determine the final volatility assumption. PPL uses a mix of historic and implied volatility to value awards. The dividend yield is based on several factor s, including PPL 's most recent dividend payment, as of the grant date and the forecasted stock price . The assumptions used in the model were: 2013 Risk-free interest rate 1.15% Expected option life 6.48 years Expected stock volatility 18.50% Dividend yield 5.00% The weighted-average grant date fair value of options granted w as : 2013 PPL $ 2.18 PPL Electric 2.19 LKE 2.18 Stock option activity for 2015 was: Weighted- Weighted Average Average Remaining Aggregate Number Exercise Contractual Total Intrinsic of Options Price Per Share Term (years) Value PPL Outstanding at beginning of period 9,042,962 $ 30.93 Anti-dilution adjustment (a) 907,737 28.06 Exercised (3,559,874) 27.35 Forfeited (5,676) 26.67 Outstanding at end of period 6,385,149 28.54 5.2 $ 42 Options exercisable at end of period 5,683,535 28.78 5.0 36 PPL Electric Outstanding at beginning of period 507,920 $ 30.04 Transfer between registrants (15,339) 29.60 Anti-dilution adjustment (a) 44,859 28.06 Exercised (224,007) 27.20 Outstanding at end of period 313,433 27.79 5.2 $ 2 Options exercisable at end of period 263,443 28.02 4.8 2 LKE Outstanding at beginning of period 623,317 $ 28.64 Anti-dilution adjustment (a) 43,236 28.06 Exercised (240,897) 28.04 Outstanding at end of period 425,656 26.08 6.7 $ 3 Options exercisable at end of period 277,101 25.80 6.5 2 (a) Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply . Substantially all stock option awards are expected to vest. For 2015 , 2014 and 2013 , PPL received $ 97 million, $67 million and $31 million in cash from stock options exercised. The related income tax benefits realized were not significant. The total intrinsic value of stock optio ns exercised for 2015 , 2014 and 2013 were $ 21 million, $ 13 million and $6 million. Compensation Expense Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric a nd LKE includes an allocation of PPL Services' expense, was: 2015 2014 2013 PPL $ 33 $ 30 $ 25 PPL Electric 14 12 10 LKE 8 8 8 See Note 8 for details of the costs recognized in discontinued operations related to the accelerated vesting of awards for former PPL Energy Supply employees. The income tax benefit related to above compensation expense was as follows: 2015 2014 2013 PPL $ 14 $ 12 $ 11 PPL Electric 6 5 4 LKE 3 3 3 The income tax benefit PPL realized from stock-based awards vested or exercised was not significant for 2015 , 2014 or 2013 . At December 31, 2015 , unrecognized compensation expense related to nonvested restricted stock, restricted stock units, performance units and stock option awards was: Weighted- Unrecognized Average Compensation Period for Expense Recognition PPL $ 8 1.6 years PPL Electric 2 1.6 years LKE 1 1.4 years
PPL Electric Utilities Corp [Member]
Stock-Based Compensation [Line Items]
Stock-Based Compensation	10. Stock-Based Compensation ( PPL, PPL Electric and LKE) In 2012, shareowners approved the SIP . This equity plan replaced the ICP and incorporated the following changes:  Eliminates the potential to pay dividend equivalents on stock options.  Eliminates the automatic lapse of restrictions on all equity awards in the event of a "potential" change in control and requires that a termination of employment occur in the event o f a change in control before restrictions lapse.  Changes the treatment of outstanding stock options upon retirement to limit the exercise period to the earlier of the end of the term ( ten years from grant ) or five years after retirement. To further align the executives’ interests with those of PPL shareowners, this plan provides that each restricted stock unit entitles the executive to accrue additional restricted st ock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units are deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awa rds granted under the ICP and the ICPKE are currently paid in cash when dividends are declared by PPL. Under the ICP, SIP and the ICPKE (together, the Plans), restricted shares of PPL common stock, rest ricted stock units, performance units and stock options may be granted to officers and other key employees of PPL , PPL Electric , LKE and other affiliated companies. Awards under the Plans are made by the Compensation, Governance and Nominating Committee ( CGNC) of the PPL Board of Directors, in the case of the ICP and SIP , and by the PPL Corporate Leadership Council ( CLC ), in the case of the ICPKE. The following table details the award limits under each of the Plans. Annual Grant Limit Annual Grant Limit Total As % of For Individual Participants - Total Plan Outstanding Annual Grant Performance Based Awards Award PPL Common Stock Limit For awards For awards Limit On First Day of Options denominated in denominated in Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) ICP (a) 15,769,431 2% 3,000,000 SIP 10,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2% 3,000,000 (a) Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP. Any portion of these award s that has not been granted may be carried over and used in any subsequent year. If any award lapses, is forfeited or the rights of the participant terminate, the shares of PPL common stock underlying such an award are again available for grant. Shares d elivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws. Res tricted Stock and Restricted Stock Units Restricted shares of PPL common stock are outstanding shares with full voting and dividend rights. Restricted stock awards are granted as a retention award for select key executives and vest when the recipient re aches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The Plans allow for the grant of restricted stock units. Restricted stock units are awards based on the fair value of PPL common stock on the date of grant . Actual PPL common shares will be issued upon completion of a restriction period, generally three years. The fair value of restricted stock and restricted stock units granted is recognized on a straight-l ine basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immedi ately upon the date of grant. Recipients of restricted stock units granted under the ICPKE may also be granted the right to receive dividend equivalents through the end of the restriction period or until the award is forfeited. Restricted stock a nd restricted stock units are subject to forfeiture or accelerated payout under the p lan provisions for termination, retirement, disability and death of employees. Restrictions lapse on r estricted stock and restricted stock units fully , in certain situati ons, as defined by each of the Plans. The weighted-average grant date fair value of restricted stock and restricted stock units granted w as : 2015 2014 2013 PPL $ 34.50 $ 31.50 $ 30.30 PPL Electric 34.41 31.81 30.55 LKE 34.89 30.98 30.00 Restricted stock and restricted stock unit activity for 2015 was : Weighted- Average Restricted Grant Date Fair Shares/Units Value Per Share PPL Nonvested, beginning of period 3,485,520 $ 30.07 Granted 1,028,009 34.50 Anti-dilution adjustments (a) 247,098 N/A Vested (3,055,205) 29.34 Forfeited (25,947) 30.70 Nonvested, end of period (b) 1,679,475 29.65 PPL Electric Nonvested, beginning of period 286,811 $ 30.04 Transfer between registrants (22,730) 29.56 Granted 75,213 34.41 Anti-dilution adjustments (a) 18,661 N/A Vested (127,507) 29.12 Forfeited (9,363) 30.51 Nonvested, end of period 221,085 29.48 LKE Nonvested, beginning of period 341,468 $ 29.76 Transfer between registrants 4,300 31.74 Granted 98,360 34.89 Anti-dilution adjustments (a) 24,587 N/A Vested (149,752) 28.55 Nonvested, end of period 318,963 29.65 (a ) Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans. (b) Excludes 1,226,193 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the spinoff, but for which distribution will not occur until the end of the original restriction period of the awards. Substantially all restricted stock and restricted stock unit a wards are expected to vest. The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was: 2015 2014 2013 PPL $ 28 $ 11 $ 12 PPL Electric 4 2 3 LKE 4 1 Performance Units Performance units are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on total shareowner return during a three -year performance period. At the end of the period, payout is determined by comparing PPL's performance to the total shareowner return of the companies included in the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that compri se the applicable index on which each years' awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance t hreshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of wheth er the performance goals have been achieved. Under the p lan provisions, performance units are subject to forfeiture upon termination of employment except for retirement, disability or death of an employee, in which case the total performance units remain outstanding and are eligible for vesting through the conclusion of the performance period. Beginning in 2014, t he fair value of performance units granted to retirement-eligible employees is recognized as compensation expense on a straight-line basis over a one-year period, the minimum vesting period required for an employee to be entitled to payout of the awards. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three -year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year. The fair value of performance units granted in 2013 and prior years is recognized as compensation expense on a straight-l ine basis over the three -year performance period . Performance units vest on a pro rata basis , in certain situations, as defined by each of the Plan s . The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the perfor mance unit . Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded b ased on events not likely to recur that had impacted PPL and the companies in the index group. PPL uses a mix of historic and implied volatility to value awards. The weighted-average assumptions used in the model were: 2015 2014 2013 Expected stock volatility 15.90% 15.80% 15.50% Expected life 3 years 3 years 3 years The weighted-average grant date fair value of performance units granted w as : 2015 2014 2013 PPL $ 36.76 $ 34.55 $ 34.15 PPL Electric 37.93 34.43 33.97 LKE 37.10 34.12 33.84 Performance unit activity for 2015 was: Weighted- Average Grant Performance Date Fair Value Units Per Share PPL Nonvested, beginning of period 1,171,716 $ 33.77 Granted 481,197 36.76 Anti-dilution adjustment (a) 90,251 N/A Vested (509,139) 32.12 Forfeited (240,485) 33.35 Nonvested, end of period (b) 993,540 33.09 PPL Electric Nonvested, beginning of period 59,615 $ 33.77 Transfer between registrants (3,676) 35.80 Granted 21,798 37.93 Anti-dilution adjustment (a) 4,627 N/A Vested (8,497) 31.38 Forfeited (6,196) 31.38 Nonvested, end of period 67,671 33.05 LKE Nonvested, beginning of period 173,946 $ 33.32 Granted 66,439 37.10 Anti-dilution adjustment (a) 13,207 N/A Vested (30,921) 31.35 Forfeited (29,507) 31.36 Nonvested, end of period 193,164 32.96 (a) Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans. (b) Excludes 322,429 performance units for which the service vesting requirement was waived for former PPL Energy Supply employees as a result of the spinoff, but for which the ultimate number of shares to be distributed will depend on the actual attainment of the performance goals at the end of the specified perfor mance periods. The total fair value of performance units vesting for the year ended December 31, 2015 and 2014 was $6 million and $5 million for PPL and insignificant for PPL Electric and LKE. Stock Options PPL’s CGNC e liminated the use of stock options and changed its long-term incentive mix to 60% performance units and 40% performance-contingent restricted stock units, resulting in 100% performance-based long-term incentive mix for equity awards granted beginning in January 2014 . U nd er the Plans, stock options had been granted with an option exercise price per share not less than the fair value of PPL's common stock on the date of grant. Options outstanding at December 31, 2015 , become exercisable in equal installments over a three -year service period beginning one year after the date of grant, assuming the individual is still employed by PPL or a subsidiary . The CGNC and CLC have discretion to accelerate the exercisability of the options, except that the exercisability of an option issued under the ICP may not be accelerated unless the individual remains employed by PPL or a subsidiary for one year from the date of grant. All options expire no later than ten years from the grant date. The options become exercisable immediately in certain situations, as defined by each of the Plans. The fair value of options granted is recognized as compensation expense on a straight-line basis over the service period or through the date at whic h the employee reaches retirement eligibility. The fair value of options granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. The fair value of each option granted is estimated using a Black-Scholes option-pricing model. PPL uses a risk-free interest rate, expected option life, expected volatility and dividend yield to value its stock options. The risk-free interest rate reflects the yield for a U.S. Treasury Strip available on the date of grant with constant rate maturity approximating the option's expected life. Expected life is calculated based on historical exercise behavior. Volatility ov er the expected term of the options is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL 's volatility in those prior periods. Management's expectations for future vol atility, considering potential changes to PPL 's business model and other economic conditions, are also reviewed in addition to the historical data to determine the final volatility assumption. PPL uses a mix of historic and implied volatility to value awards. The dividend yield is based on several factor s, including PPL 's most recent dividend payment, as of the grant date and the forecasted stock price . The assumptions used in the model were: 2013 Risk-free interest rate 1.15% Expected option life 6.48 years Expected stock volatility 18.50% Dividend yield 5.00% The weighted-average grant date fair value of options granted w as : 2013 PPL $ 2.18 PPL Electric 2.19 LKE 2.18 Stock option activity for 2015 was: Weighted- Weighted Average Average Remaining Aggregate Number Exercise Contractual Total Intrinsic of Options Price Per Share Term (years) Value PPL Outstanding at beginning of period 9,042,962 $ 30.93 Anti-dilution adjustment (a) 907,737 28.06 Exercised (3,559,874) 27.35 Forfeited (5,676) 26.67 Outstanding at end of period 6,385,149 28.54 5.2 $ 42 Options exercisable at end of period 5,683,535 28.78 5.0 36 PPL Electric Outstanding at beginning of period 507,920 $ 30.04 Transfer between registrants (15,339) 29.60 Anti-dilution adjustment (a) 44,859 28.06 Exercised (224,007) 27.20 Outstanding at end of period 313,433 27.79 5.2 $ 2 Options exercisable at end of period 263,443 28.02 4.8 2 LKE Outstanding at beginning of period 623,317 $ 28.64 Anti-dilution adjustment (a) 43,236 28.06 Exercised (240,897) 28.04 Outstanding at end of period 425,656 26.08 6.7 $ 3 Options exercisable at end of period 277,101 25.80 6.5 2 (a) Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply . Substantially all stock option awards are expected to vest. For 2015 , 2014 and 2013 , PPL received $ 97 million, $67 million and $31 million in cash from stock options exercised. The related income tax benefits realized were not significant. The total intrinsic value of stock optio ns exercised for 2015 , 2014 and 2013 were $ 21 million, $ 13 million and $6 million. Compensation Expense Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric a nd LKE includes an allocation of PPL Services' expense, was: 2015 2014 2013 PPL $ 33 $ 30 $ 25 PPL Electric 14 12 10 LKE 8 8 8 See Note 8 for details of the costs recognized in discontinued operations related to the accelerated vesting of awards for former PPL Energy Supply employees. The income tax benefit related to above compensation expense was as follows: 2015 2014 2013 PPL $ 14 $ 12 $ 11 PPL Electric 6 5 4 LKE 3 3 3 The income tax benefit PPL realized from stock-based awards vested or exercised was not significant for 2015 , 2014 or 2013 . At December 31, 2015 , unrecognized compensation expense related to nonvested restricted stock, restricted stock units, performance units and stock option awards was: Weighted- Unrecognized Average Compensation Period for Expense Recognition PPL $ 8 1.6 years PPL Electric 2 1.6 years LKE 1 1.4 years
LG And E And KU Energy LLC [Member]
Stock-Based Compensation [Line Items]
Stock-Based Compensation	10. Stock-Based Compensation ( PPL, PPL Electric and LKE) In 2012, shareowners approved the SIP . This equity plan replaced the ICP and incorporated the following changes:  Eliminates the potential to pay dividend equivalents on stock options.  Eliminates the automatic lapse of restrictions on all equity awards in the event of a "potential" change in control and requires that a termination of employment occur in the event o f a change in control before restrictions lapse.  Changes the treatment of outstanding stock options upon retirement to limit the exercise period to the earlier of the end of the term ( ten years from grant ) or five years after retirement. To further align the executives’ interests with those of PPL shareowners, this plan provides that each restricted stock unit entitles the executive to accrue additional restricted st ock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units are deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awa rds granted under the ICP and the ICPKE are currently paid in cash when dividends are declared by PPL. Under the ICP, SIP and the ICPKE (together, the Plans), restricted shares of PPL common stock, rest ricted stock units, performance units and stock options may be granted to officers and other key employees of PPL , PPL Electric , LKE and other affiliated companies. Awards under the Plans are made by the Compensation, Governance and Nominating Committee ( CGNC) of the PPL Board of Directors, in the case of the ICP and SIP , and by the PPL Corporate Leadership Council ( CLC ), in the case of the ICPKE. The following table details the award limits under each of the Plans. Annual Grant Limit Annual Grant Limit Total As % of For Individual Participants - Total Plan Outstanding Annual Grant Performance Based Awards Award PPL Common Stock Limit For awards For awards Limit On First Day of Options denominated in denominated in Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) ICP (a) 15,769,431 2% 3,000,000 SIP 10,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2% 3,000,000 (a) Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP. Any portion of these award s that has not been granted may be carried over and used in any subsequent year. If any award lapses, is forfeited or the rights of the participant terminate, the shares of PPL common stock underlying such an award are again available for grant. Shares d elivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws. Res tricted Stock and Restricted Stock Units Restricted shares of PPL common stock are outstanding shares with full voting and dividend rights. Restricted stock awards are granted as a retention award for select key executives and vest when the recipient re aches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The Plans allow for the grant of restricted stock units. Restricted stock units are awards based on the fair value of PPL common stock on the date of grant . Actual PPL common shares will be issued upon completion of a restriction period, generally three years. The fair value of restricted stock and restricted stock units granted is recognized on a straight-l ine basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immedi ately upon the date of grant. Recipients of restricted stock units granted under the ICPKE may also be granted the right to receive dividend equivalents through the end of the restriction period or until the award is forfeited. Restricted stock a nd restricted stock units are subject to forfeiture or accelerated payout under the p lan provisions for termination, retirement, disability and death of employees. Restrictions lapse on r estricted stock and restricted stock units fully , in certain situati ons, as defined by each of the Plans. The weighted-average grant date fair value of restricted stock and restricted stock units granted w as : 2015 2014 2013 PPL $ 34.50 $ 31.50 $ 30.30 PPL Electric 34.41 31.81 30.55 LKE 34.89 30.98 30.00 Restricted stock and restricted stock unit activity for 2015 was : Weighted- Average Restricted Grant Date Fair Shares/Units Value Per Share PPL Nonvested, beginning of period 3,485,520 $ 30.07 Granted 1,028,009 34.50 Anti-dilution adjustments (a) 247,098 N/A Vested (3,055,205) 29.34 Forfeited (25,947) 30.70 Nonvested, end of period (b) 1,679,475 29.65 PPL Electric Nonvested, beginning of period 286,811 $ 30.04 Transfer between registrants (22,730) 29.56 Granted 75,213 34.41 Anti-dilution adjustments (a) 18,661 N/A Vested (127,507) 29.12 Forfeited (9,363) 30.51 Nonvested, end of period 221,085 29.48 LKE Nonvested, beginning of period 341,468 $ 29.76 Transfer between registrants 4,300 31.74 Granted 98,360 34.89 Anti-dilution adjustments (a) 24,587 N/A Vested (149,752) 28.55 Nonvested, end of period 318,963 29.65 (a ) Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans. (b) Excludes 1,226,193 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the spinoff, but for which distribution will not occur until the end of the original restriction period of the awards. Substantially all restricted stock and restricted stock unit a wards are expected to vest. The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was: 2015 2014 2013 PPL $ 28 $ 11 $ 12 PPL Electric 4 2 3 LKE 4 1 Performance Units Performance units are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on total shareowner return during a three -year performance period. At the end of the period, payout is determined by comparing PPL's performance to the total shareowner return of the companies included in the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that compri se the applicable index on which each years' awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance t hreshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of wheth er the performance goals have been achieved. Under the p lan provisions, performance units are subject to forfeiture upon termination of employment except for retirement, disability or death of an employee, in which case the total performance units remain outstanding and are eligible for vesting through the conclusion of the performance period. Beginning in 2014, t he fair value of performance units granted to retirement-eligible employees is recognized as compensation expense on a straight-line basis over a one-year period, the minimum vesting period required for an employee to be entitled to payout of the awards. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three -year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year. The fair value of performance units granted in 2013 and prior years is recognized as compensation expense on a straight-l ine basis over the three -year performance period . Performance units vest on a pro rata basis , in certain situations, as defined by each of the Plan s . The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the perfor mance unit . Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded b ased on events not likely to recur that had impacted PPL and the companies in the index group. PPL uses a mix of historic and implied volatility to value awards. The weighted-average assumptions used in the model were: 2015 2014 2013 Expected stock volatility 15.90% 15.80% 15.50% Expected life 3 years 3 years 3 years The weighted-average grant date fair value of performance units granted w as : 2015 2014 2013 PPL $ 36.76 $ 34.55 $ 34.15 PPL Electric 37.93 34.43 33.97 LKE 37.10 34.12 33.84 Performance unit activity for 2015 was: Weighted- Average Grant Performance Date Fair Value Units Per Share PPL Nonvested, beginning of period 1,171,716 $ 33.77 Granted 481,197 36.76 Anti-dilution adjustment (a) 90,251 N/A Vested (509,139) 32.12 Forfeited (240,485) 33.35 Nonvested, end of period (b) 993,540 33.09 PPL Electric Nonvested, beginning of period 59,615 $ 33.77 Transfer between registrants (3,676) 35.80 Granted 21,798 37.93 Anti-dilution adjustment (a) 4,627 N/A Vested (8,497) 31.38 Forfeited (6,196) 31.38 Nonvested, end of period 67,671 33.05 LKE Nonvested, beginning of period 173,946 $ 33.32 Granted 66,439 37.10 Anti-dilution adjustment (a) 13,207 N/A Vested (30,921) 31.35 Forfeited (29,507) 31.36 Nonvested, end of period 193,164 32.96 (a) Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans. (b) Excludes 322,429 performance units for which the service vesting requirement was waived for former PPL Energy Supply employees as a result of the spinoff, but for which the ultimate number of shares to be distributed will depend on the actual attainment of the performance goals at the end of the specified perfor mance periods. The total fair value of performance units vesting for the year ended December 31, 2015 and 2014 was $6 million and $5 million for PPL and insignificant for PPL Electric and LKE. Stock Options PPL’s CGNC e liminated the use of stock options and changed its long-term incentive mix to 60% performance units and 40% performance-contingent restricted stock units, resulting in 100% performance-based long-term incentive mix for equity awards granted beginning in January 2014 . U nd er the Plans, stock options had been granted with an option exercise price per share not less than the fair value of PPL's common stock on the date of grant. Options outstanding at December 31, 2015 , become exercisable in equal installments over a three -year service period beginning one year after the date of grant, assuming the individual is still employed by PPL or a subsidiary . The CGNC and CLC have discretion to accelerate the exercisability of the options, except that the exercisability of an option issued under the ICP may not be accelerated unless the individual remains employed by PPL or a subsidiary for one year from the date of grant. All options expire no later than ten years from the grant date. The options become exercisable immediately in certain situations, as defined by each of the Plans. The fair value of options granted is recognized as compensation expense on a straight-line basis over the service period or through the date at whic h the employee reaches retirement eligibility. The fair value of options granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. The fair value of each option granted is estimated using a Black-Scholes option-pricing model. PPL uses a risk-free interest rate, expected option life, expected volatility and dividend yield to value its stock options. The risk-free interest rate reflects the yield for a U.S. Treasury Strip available on the date of grant with constant rate maturity approximating the option's expected life. Expected life is calculated based on historical exercise behavior. Volatility ov er the expected term of the options is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL 's volatility in those prior periods. Management's expectations for future vol atility, considering potential changes to PPL 's business model and other economic conditions, are also reviewed in addition to the historical data to determine the final volatility assumption. PPL uses a mix of historic and implied volatility to value awards. The dividend yield is based on several factor s, including PPL 's most recent dividend payment, as of the grant date and the forecasted stock price . The assumptions used in the model were: 2013 Risk-free interest rate 1.15% Expected option life 6.48 years Expected stock volatility 18.50% Dividend yield 5.00% The weighted-average grant date fair value of options granted w as : 2013 PPL $ 2.18 PPL Electric 2.19 LKE 2.18 Stock option activity for 2015 was: Weighted- Weighted Average Average Remaining Aggregate Number Exercise Contractual Total Intrinsic of Options Price Per Share Term (years) Value PPL Outstanding at beginning of period 9,042,962 $ 30.93 Anti-dilution adjustment (a) 907,737 28.06 Exercised (3,559,874) 27.35 Forfeited (5,676) 26.67 Outstanding at end of period 6,385,149 28.54 5.2 $ 42 Options exercisable at end of period 5,683,535 28.78 5.0 36 PPL Electric Outstanding at beginning of period 507,920 $ 30.04 Transfer between registrants (15,339) 29.60 Anti-dilution adjustment (a) 44,859 28.06 Exercised (224,007) 27.20 Outstanding at end of period 313,433 27.79 5.2 $ 2 Options exercisable at end of period 263,443 28.02 4.8 2 LKE Outstanding at beginning of period 623,317 $ 28.64 Anti-dilution adjustment (a) 43,236 28.06 Exercised (240,897) 28.04 Outstanding at end of period 425,656 26.08 6.7 $ 3 Options exercisable at end of period 277,101 25.80 6.5 2 (a) Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply . Substantially all stock option awards are expected to vest. For 2015 , 2014 and 2013 , PPL received $ 97 million, $67 million and $31 million in cash from stock options exercised. The related income tax benefits realized were not significant. The total intrinsic value of stock optio ns exercised for 2015 , 2014 and 2013 were $ 21 million, $ 13 million and $6 million. Compensation Expense Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric a nd LKE includes an allocation of PPL Services' expense, was: 2015 2014 2013 PPL $ 33 $ 30 $ 25 PPL Electric 14 12 10 LKE 8 8 8 See Note 8 for details of the costs recognized in discontinued operations related to the accelerated vesting of awards for former PPL Energy Supply employees. The income tax benefit related to above compensation expense was as follows: 2015 2014 2013 PPL $ 14 $ 12 $ 11 PPL Electric 6 5 4 LKE 3 3 3 The income tax benefit PPL realized from stock-based awards vested or exercised was not significant for 2015 , 2014 or 2013 . At December 31, 2015 , unrecognized compensation expense related to nonvested restricted stock, restricted stock units, performance units and stock option awards was: Weighted- Unrecognized Average Compensation Period for Expense Recognition PPL $ 8 1.6 years PPL Electric 2 1.6 years LKE 1 1.4 years

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2015
Retirement and Postemployment Benefits [Abstract]
Retirement and Postemployment Benefits	11. Retirem ent and Postemployment Benefits ( All Registrants ) Defined Benefits T he majority of PPL 's subsidiaries domestic e mployees are eligible for pension benefits under non-contributory defined benefit pension plans with benefits based on length of service and final average pay, as defined by the plans. Effective January 1, 2012, PPL's primary defined benefit pension plan was closed t o all newly hired salaried employees. Effective July 1, 2014, PPL's primary defined benefit pension plan was closed to all newly hired bargaining unit employees. Newly hired employees are eligible to participate in the PPL Retirement Savings Plan , a 401( k) savings plan with enhanced employer contributions. The defined benefit pension plans of LKE and its subsidiaries were closed to new salaried and bargaining unit employees hired after December 31, 2005 . Employees hired after December 31, 2005 rece ive additional company contributions above the standard matching contributions to their savings plans. Effective April 1, 2010 , the principal defined benefit pension plan applicable to WPD (South West) and WPD (South Wales) was closed to most new employee s, except for those meeting specific grandfathered participation rights . WPD Midlands' defined benefit plan had been closed to new members, except for those meeting specific grandfathered participation rights, prior to acquisition. New employees not elig ible to participate in the plan s are offered benefits unde r a defined contribution plan. PPL and certain of its subsidiaries also provide supplemental retirement benefits to executives and other key management employees through unfunded nonqualified retir ement plans. The majority of employees of PPL's domestic subsidiaries are eligible for certain health care and life insurance benefits upon retirement through contributory plans. Effective January 1, 2014, the PPL Postretirement Medical Plan was closed t o all newly hired salaried employees. Effective July 1, 2014, the PPL Postretirement Medical Plan was closed to all newly hired bargaining unit employees. Postretirement health benefits may be paid from 401(h) accounts established as part of the PPL Reti rement Plan and the LG&E and KU Retirement Plan within the PPL Services Corporation Master Trust, funded VEBA trusts and company funds. WPD does not sponsor any postretirement benefit plans other than pensions. ( PPL ) The following table provides the components of net periodic defined benefit costs for PPL's domestic (U.S.) and WPD’s (U.K.) pension and other postretirement benefit plans for the years ended December 31. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 Net periodic defined benefit costs (credits): Service cost $ 96 $ 97 $ 119 $ 79 $ 71 $ 69 $ 11 $ 12 $ 13 Interest cost 194 224 205 314 354 320 26 31 29 Expected return on plan assets (258) (287) (283) (523) (521) (465) (26) (26) (25) Amortization of: Prior service cost (credit) 7 20 22 1 1 Actuarial (gain) loss 84 28 77 158 132 150 1 6 Net periodic defined benefit costs (credits) prior to termination benefits 123 82 140 28 36 75 12 18 23 Termination benefits 13 3 Net periodic defined benefit costs (credits) $ 123 $ 95 $ 140 $ 28 $ 36 $ 78 $ 12 $ 18 $ 23 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Divestiture (a) $ (353) $ (6) Net (gain) loss 63 $ 574 $ (304) $ 508 $ 354 $ 76 (9) $ 22 $ (67) Prior service cost (credit) 18 (8) 7 Amortization of: Prior service (cost) credit (7) (20) (22) (1) (1) Actuarial gain (loss) (85) (28) (77) (158) (132) (150) (1) (6) Total recognized in OCI and regulatory assets/liabilities (b) (364) 518 (403) 350 222 (75) (16) 28 (73) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (b) $ (241) $ 613 $ (263) $ 378 $ 258 $ 3 $ (4) $ 46 $ (50) (a) As a result of the spinoff of PPL Energy Supply, amounts in AOCI were allocated to certain former active and inactive employees of PPL Energy Supply and included in the distribution . See Note 8 for additional details. (b) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. As a result, WPD does not record regulatory assets/liabilities. For PPL's U.S. pension benefits and for other postretirement benefits, the amounts recog nized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 OCI $ (269) $ 319 $ (210) $ 12 $ 7 $ (37) Regulatory assets/liabilities (95) 199 (193) (28) 21 (36) Total recognized in OCI and regulatory assets/liabilities $ (364) $ 518 $ (403) $ (16) $ 28 $ (73) The estimated amounts to be amortized from AOCI and regulatory assets /liabilities into net periodic defined benef it costs in 2016 are as follows: Pension Benefits U.S. U.K. Prior service cost (credit) $ 8 Actuarial (gain) loss 49 $ 151 Total $ 57 $ 151 Amortization from Balance Sheet: AOCI $ 12 $ 151 Regulatory assets/liabilities 45 Total $ 57 $ 151 ( LKE ) The following table provides the components of net periodic defined benefit costs for LKE’s pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 Net periodic defined benefit costs (credits): Service cost $ 26 $ 21 $ 26 $ 5 $ 4 $ 5 Interest cost 68 66 62 9 9 8 Expected return on plan assets (88) (82) (82) (6) (4) (5) Amortization of: Prior service cost (credit) 7 5 5 3 2 3 Actuarial (gain) loss (a) 37 12 33 (1) Net periodic defined benefit costs (credit) $ 50 $ 22 $ 44 $ 11 $ 10 $ 11 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (gain) loss $ 20 $ 162 $ (116) $ (15) $ 26 $ (14) Prior service cost (credit) 19 23 6 Amortization of: Prior service (cost) credit (7) (5) (5) (3) (2) (3) Actuarial gain (loss) (37) (12) (33) 1 Total recognized in OCI and regulatory assets/liabilities (5) 168 (154) (18) 31 (17) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 45 $ 190 $ (110) $ (7) $ 41 $ (6) (a ) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LKE’s pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $ 9 million. For LKE's pension and other postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 3 1 were as follows : Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 OCI $ 4 $ 84 $ (46) $ (2) $ 9 $ (1) Regulatory assets/liabilities (9) 84 (108) (16) 22 (16) Total recognized in OCI and regulatory assets/liabilities $ (5) $ 168 $ (154) $ (18) $ 31 $ (17) The estimate d amounts to be amortized from AOCI and regulatory assets /liabilities into net periodic defined benef it costs for LKE in 2016 are as follows . Other Pension Postretirement Benefits Benefits Prior service cost (credit) $ 8 $ 2 Actuarial (gain) loss 20 Total $ 28 $ 2 Amortization from Balance Sheet: AOCI $ 2 $ 1 Regulatory assets/liabilities 26 1 Total $ 28 $ 2 (LG&E) The following table provides the components of net periodic defined benefit costs for LG&E’s pension benefit plan for the years ended December 31. Pension Benefits 2015 2014 2013 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 $ 2 Interest cost 14 15 14 Expected return on plan assets (20) (19) (20) Amortization of: Prior service cost (credit) 3 2 2 Actuarial (gain) loss (a) 11 6 14 Net periodic defined benefit costs (credits) $ 9 $ 5 $ 12 Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: Net (gain) loss $ 8 $ 14 $ (20) Prior service cost (credit) 10 9 Amortization of: Prior service (cost) credit (3) (2) (2) Actuarial gain (loss) (11) (6) (14) Total recognized in regulatory assets/liabilities 4 15 (36) Total recognized in net periodic defined benefit costs and regulatory assets $ 13 $ 20 $ (24) (a) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E’s pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $ 3 million. The estimated amounts to be amortized from regulatory assets into net periodic defined benefit costs for LG&E in 2016 are as foll ows. Pension Benefits Prior service cost (credit) $ 5 Actuarial (gain) loss 7 Total $ 12 ( All Registrants ) The following n et periodic defined benefit costs (credits) were charged to operating expense or regulatory assets , excluding amounts charged to construction and other non-expense accounts. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 PPL $ 71 $ 45 $ 72 $ (21) $ (9) $ 33 $ 8 $ 10 $ 13 PPL Electric (a) 15 12 18 2 3 LKE (b) 37 17 32 8 7 8 LG&E (b) 12 5 14 4 4 4 KU (a) (b) 9 3 9 2 2 2 (a) PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. (b) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between net periodic defined benefit costs calculated in acco rdance with LKE’s, LG&E’s and KU’s pension accounting policy and the net periodic defined benefit costs calculated using a 15 year amortization period for gains and losses is recorded as a regulatory asset. Of the costs charge d to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts, $ 4 million for LG&E and $ 1 million for KU were recorded as regulatory assets. In the table above LG&E amounts inc lude costs for the specific plans its sponsors and the following allocated costs of defined benefit plans sponsored by LKE , based on its participation in those plans, which management believes are reasonable : Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 LG&E $ 5 $ 2 $ 5 $ 4 $ 4 $ 4 ( PPL, LKE and LG&E ) PPL, LKE and LG&E adopted the new mortality tables issued by the Society of Actuaries in October 2014 (RP-2014 base tables) for all U.S. defined benefit pension and other postretirement benefit plans at December 31, 2015 . In addition , PPL , LKE and LG&E updated the basis for estimating projected mortality improvements and selected the IRS BB-2D two-dimensional improvement scale on a generational basis for all U.S. defined benefit pension and other postretirement benefit plans. The se n ew mortality assumptions r eflect the recognition of both improved life expectancies and the expectation of continuing improvements in life expectancies . The use of the new base tables and improvement scale resulted in an increase to U.S. defined benefit p ension and other postretirement benefit obligations, an increase to future expense and a decrease in funded status. The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2015 2014 2015 2014 PPL Discount rate 4.59% 4.25% 3.68% 3.85% 4.48% 4.09% Rate of compensation increase 3.93% 3.91% 4.00% 4.00% 3.91% 3.86% LKE Discount rate 4.56% 4.25% 4.49% 4.06% Rate of compensation increase 3.50% 3.50% 3.50% 3.50% LG&E Discount rate 4.49% 4.20% The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 PPL Discount rate 4.25% 5.12% 4.22% 3.85% 4.41% 4.27% 4.09% 4.91% 4.00% Rate of compensation increase 3.91% 3.97% 3.98% 4.00% 4.00% 4.00% 3.86% 3.96% 3.97% Expected return on plan assets (a) 7.00% 7.00% 7.03% 7.19% 7.19% 7.16% 6.06% 5.96% 5.94% LKE Discount rate 4.25% 5.18% 4.24% 4.06% 4.91% 3.99% Rate of compensation increase 3.50% 4.00% 4.00% 3.50% 4.00% 4.00% Expected return on plan assets (a) 7.00% 7.00% 7.10% 6.82% 6.75% 6.76% LG&E Discount rate 4.20% 5.13% 4.20% Expected return on plan assets (a) 7.00% 7.00% 7.10% (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. (PPL and LKE ) The following table provides the assumed health care cost trend rates for the year s ended December 31 : 2015 2014 2013 PPL and LKE Health care cost trend rate assumed for next year - obligations 6.8% 7.2% 7.6% - cost 7.2% 7.6% 8.0% Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) - obligations 5.0% 5.0% 5.0% - cost 5.0% 5.0% 5.5% Year that the rate reaches the ultimate trend rate - obligations 2020 2020 2020 - cost 2020 2020 2019 A one percentage point change in the assumed health care costs trend rate assumption would have had the following effects on the other post retirement benefit plans in 2015 : One Percentage Point Increase Decrease Effect on accumulated postretirement benefit obligation PPL $ 6 $ (5) LKE 5 (4) ( PPL ) The funded status of PPL's plans at December 31 was as follows: Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2015 2014 2015 2014 Change in Benefit Obligation Benefit Obligation, beginning of period $ 5,399 $ 4,428 $ 8,523 $ 8,143 $ 716 $ 650 Service cost 96 97 79 71 11 12 Interest cost 194 224 314 354 26 31 Participant contributions 15 16 13 12 Plan amendments 19 (7) 6 Actuarial (gain) loss (193) 887 200 747 (37) 59 Divestiture (a) (1,416) (76) Termination benefits 13 Gross benefits paid (b) (236) (243) (391) (411) (58) (55) Federal subsidy 1 1 Currency conversion (336) (397) Benefit Obligation, end of period 3,863 5,399 8,404 8,523 596 716 Change in Plan Assets Plan assets at fair value, beginning of period 4,462 4,009 7,734 7,284 484 446 Actual return on plan assets 2 600 205 895 (2) 62 Employer contributions 158 96 366 311 17 15 Participant contributions 15 16 13 12 Divestiture (a) (1,159) (80) Gross benefits paid (b) (236) (243) (391) (411) (53) (51) Currency conversion (304) (361) Plan assets at fair value, end of period 3,227 4,462 7,625 7,734 379 484 Funded Status, end of period $ (636) $ (937) $ (779) $ (789) $ (217) $ (232) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 2 $ 1 Current liability $ (10) $ (10) $ (1) (3) (3) Noncurrent liability (626) (668) $ (779) (788) (216) (196) Noncurrent liability of discontinued operations (259) (34) Net amount recognized, end of period $ (636) $ (937) $ (779) $ (789) $ (217) $ (232) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 53 $ 41 $ 1 Net actuarial (gain) loss 977 1,353 $ 2,684 $ 2,334 37 $ 54 Total (c) $ 1,030 $ 1,394 $ 2,684 $ 2,334 $ 38 $ 54 Total accumulated benefit obligation for defined benefit pension plans $ 3,590 $ 4,946 $ 7,747 $ 7,867 (a ) As a result of the spinoff of PPL Energy Supply, obligations and assets attributable to certain former active and inactive employees of PPL Energy Supply were transferred to Talen Energy plans. ( b ) Certain U.S. pension plans offered a limited-time program in 2014 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump sum payment. G ross benefits paid i ncludes $33 million of lump-sum cash pa yments made to terminated vested participants in 2014 in connection with these offerings. (c) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and a s a result, does not record regulatory assets/lia bilities . For PPL's U.S. pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 AOCI $ 275 $ 714 $ 18 $ 30 Regulatory assets/liabilities 755 680 20 24 Total $ 1,030 $ 1,394 $ 38 $ 54 The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets: U.S. U.K. PBO in excess of plan assets PBO in excess of plan assets 2015 2014 2015 2014 Projected benefit obligation $ 3,863 $ 5,399 $ 8,404 $ 8,523 Fair value of plan assets 3,227 4,462 7,625 7,734 U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2015 2014 2015 2014 Accumulated benefit obligation $ 3,590 $ 4,946 $ 3,532 $ 3,592 Fair value of plan assets 3,227 4,462 3,287 3,321 ( LKE ) The funded status of LKE's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,608 $ 1,328 $ 234 $ 193 Service cost 26 21 5 4 Interest cost 68 66 9 9 Participant contributions 7 7 Plan amendments (a) 19 23 6 Actuarial (gain) loss (74) 253 (22) 32 Gross benefits paid (b) (59) (83) (18) (17) Federal subsidy 1 Benefit Obligation, end of period 1,588 1,608 216 234 Change in Plan Assets Plan assets at fair value, beginning of period 1,301 1,173 82 74 Actual return on plan assets (7) 173 10 Employer contributions 54 38 17 8 Participant contributions 7 7 Gross benefits paid (b) (59) (83) (18) (17) Plan assets at fair value, end of period 1,289 1,301 88 82 Funded Status, end of period $ (299) $ (307) $ (128) $ (152) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 2 $ 2 Current liability $ (3) $ (3) (3) (3) Noncurrent liability (296) (304) (127) (151) Net amount recognized, end of period $ (299) $ (307) $ (128) $ (152) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 54 $ 43 $ 9 $ 12 Net actuarial (gain) loss 338 354 (19) (4) Total $ 392 $ 397 $ (10) $ 8 Total accumulated benefit obligation for defined benefit pension plans $ 1,452 $ 1,461 (a) The pension plans were amended in December 2015 allowing terminated vested participants to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. The projected benefit obligation increased by $ 19 million as a result of the amendment. The plans were amended in December 2014 to enhance the early retirement factors for all plan participants retiring on or after January 1, 2015. These modifications resulted in an increase o f $ 23 million in the plans’ projected benefit obligations as of December 31, 2014. ( b ) Certain LKE pension plans offered a limited-time program in 2014 during which terminated vested participants could elect to receive thei r accrued pension benefit as a one-time lump-sum payment. The gross benefits paid includes $ 33 million of lump-sum cash payments made to terminated vested participants during 2014 in connection with these offerings. T he amounts recognized in AOCI and regulatory assets /liabilities at December 31 were as follows : Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 AOCI $ 70 $ 65 $ 7 $ 8 Regulatory assets/liabilities 322 332 (17) Total $ 392 $ 397 $ (10) $ 8 The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligations (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2015 2014 Projected benefit obligation $ 1,588 $ 1,608 Fair value of plan assets 1,289 1,301 ABO in excess of plan assets 2015 2014 Accumulated benefit obligation $ 1,452 $ 1,461 Fair value of plan assets 1,289 1,301 (LG&E) T he funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2015 2014 Change in Benefit Obligation Benefit Obligation, beginning of period $ 331 $ 291 Service cost 1 1 Interest cost 14 15 Plan amendments (a) 10 9 Actuarial (gain) loss (15) 36 Gross benefits paid (b) (15) (21) Benefit Obligation, end of period 326 331 Change in Plan Assets Plan assets at fair value, beginning of period 301 281 Actual return on plan assets (2) 41 Employer contributions 13 Gross benefits paid (b) (15) (21) Plan assets at fair value, end of period 297 301 Funded Status, end of period $ (29) $ (30) Amounts recognized in the Balance Sheets consist of: Noncurrent liability $ (29) $ (30) Net amount recognized, end of period $ (29) $ (30) Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost (credit) $ 29 $ 22 Net actuarial (gain) loss 95 98 Total $ 124 $ 120 Total accumulated benefit obligation for defined benefit pension plan $ 326 $ 330 ( a) The plan was amended in December 2015 allowing terminated vested participants to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. The projected benefit obligation increased by $ 10 million as a result of the amendment. The plan was amended in December 2014 to enhance the early retirement factors for all plan participants retirin g on or after January 1, 2015. Th e projected benefit obligation increased by $ 9 million as a result of the amendment. ( b ) LG&E's pension plan offered a limited-time program in 2014 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The gross benefits paid includes $ 8 million of lump-sum cash payments made to terminated vested participants in 2014 in connection with this offering. LG&E's pension plan had projected and accumulated benefit obligations in excess of plan assets at December 31, 2015 and 2014 . In addition to the plan it sponsors, LG&E is allocated a portion of the funded status and costs of certain defined benefit plans sponsored by LKE based on its participation in those plans, which management believes are reasonable. The actuarial ly determined obligations of current active employees and retired employees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to LG&E resulted in liabilities a t December 31 as follows : 2015 2014 Pension $ 26 $ 27 Other postretirement benefits 77 85 ( PPL Electric ) Although PPL Electric does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by PPL Services based on its participation in those plans , which management believes are reasonable . As a result of the spinoff of PPL Energy Supply, pension and other postretirement plans were remeasured resulting in adjustments to PPL Electric’s allocated balances of $56 million, reflected as a non-cash contribution on the Statement of Equity. The actuarially determined obligations of current active employees and retirees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. A llocations t o PPL Electric resulted in liabilit ies at December 31 as follows . 2015 2014 Pension $ 183 $ 212 Other postretirement benefits 67 40 (KU) Although KU does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE based on its participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of KU are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to KU resulted in liabilities at December 31 as follows. 2015 2014 Pension $ 46 $ 59 Other postretirement benefits 42 52 Plan Assets - U.S. Pension Plans (PPL, LKE and LG&E) PPL 's primary legacy pension plan and the pension plans sponsored by LKE are invested in the PPL Services Corporation Master Trust (the Master Trust) that also includes 401(h) account s that are restricted for certain other postretirement benefit obligations of PPL and LKE . The investment strategy for the Master T rust is to achieve a risk-adjusted return on a mix of assets that, in combination with PPL 's funding policy, will ensure that sufficie nt assets are available to provide long-term growth and liquidity for benefit payments , while also managing the duration of the assets to complement the duration of the liabilities. The M aster T rust benefits from a wide diversification of asset types, inv estment fund strategies and external investment fund managers, and therefore ha s no significant concentration of risk. The investment polic y of the Master Trust outline s investment objective s and define s the responsibilities of the EBPB, external investme nt managers , investment advisor and trustee and custodian . The investment polic y is reviewed annually by PPL 's Board of Directors. The EBPB created a risk management framework around the trust assets and pension liabilities. This framework considers the trust assets as being composed of three sub-portfolios: growth, immunizing and liquidity portfolios. The growth portfolio is comprised of investments that generate a return at a reasonable risk, including equity securities, certain debt securities and a lternative investments. The immunizing portfolio consists of debt securities, generally with long durations, and derivative positions. The immunizing portfolio is designed to offset a portion of the change in the pension liabilities due to changes in int erest rates. The liquidity portfolio consists primarily of cash and cash equivalents. Target allocation ranges have been developed for each portfolio on a plan basis based on input from external consultants with a goal of limiting funded status volatilit y. The EBPB monitors the investments in each p ortfolio on a plan basis , and seeks to obtain a target portfolio that emphasizes reduction of risk of loss from market volatility. In pursu ing that goal, the EBPB establishes revised guidelines from time to t ime. EBPB investment guidelines as of the end of 2015 are presented below. The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2015 Target Asset 2015 (a) 2014 Allocation (a) Growth Portfolio 51% 51% 50% Equity securities 25% 26% Debt securities (b) 13% 13% Alternative investments 13% 12% Immunizing Portfolio 47% 47% 48% Debt securities (b) 42% 44% Derivatives 5% 3% Liquidity Portfolio 2% 2% 2% Total 100% 100% 100% (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes . (LKE) LKE has pension plan s, including LG&E's plan, whose assets are invested solely in the Master Trust , which is fully disclos ed below. The fair value of the s e plan s ' assets of $ 1.3 b illion at December 31, 2015 and 2014 represents a n interest of approximately 40% and 28% in the M aster T rust . (LG&E) LG&E has a pension plan whose assets are invested solely in the Master Tru st , which is fully disclosed below. The fair value of this plan's assets of $ 297 million and $ 301 million at December 31, 2015 and 2014 represents a n interest of approximately 9% and 6% in the M aster T rust . (PPL, LKE and LG&E ) The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 225 $ 225 $ 246 $ 246 Equity securities: U.S.: Large-cap 87 87 114 114 Large-cap fund measured at NAV (a) 197 318 Small-cap 85 85 145 145 International equity fund at NAV (a) 454 615 Commingled debt measured at NAV (a) 514 818 Debt securities: U.S. Treasury and U.S. government sponsored agency 501 492 $ 9 723 706 $ 17 Residential/commercial backed securities 3 3 2 2 Corporate 747 737 $ 10 1,109 1,088 $ 21 International government 4 4 8 8 Other 7 7 9 9 Alternative investments: Commodities measured at NAV (a) 70 90 Real estate measured at NAV (a) 118 148 Private equity measured at NAV (a) 81 104 Hedge funds measured at NAV (a) 171 223 Derivatives: Interest rate swaps and swaptions 80 80 92 92 Other 11 11 12 12 Insurance contracts 32 32 33 33 PPL Services Corporation Master Trust assets, at fair value 3,387 $ 889 $ 851 $ 42 4,809 $ 1,211 $ 1,228 $ 54 Receivables and payables, net (b) (49) (41) 401(h) accounts restricted for other postretirement benefit obligations (111) (136) Total PPL Services Corporation Master Trust pension assets (c) $ 3,227 $ 4,632 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled alon g with interest and dividends earned but not yet received. (c) As a result of the spinoff of PPL Energy Supply, $1,159 million of assets were transferred to Talen Energy in 2015, attributable to former active and inactive employees of PPL Energy Supply that had participated in PPL’s pension plan. An additional $170 million of assets of the PPL Montana pension plan transferred to Talen Energy, as that entire plan was assumed by Talen Energy. A reconciliation of the Master Trust assets cla ssified as Level 3 at December 31, 2015 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 21 $ 33 $ 54 Actual return on plan assets Relating to assets still held at the reporting date 2 2 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (10) (3) (13) Balance at end of period $ 10 $ 32 $ 42 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2014 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 23 $ 37 $ 60 Actual return on plan assets Relating to assets still held at the reporting date (1) 1 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (5) (5) Balance at end of period $ 21 $ 33 $ 54 The fair value measurements of cash and cash equivalents are based on the amounts on deposit. The market approach is used to measure fair value of equity securities. The fair value measurements of equity securities (excluding commingled funds), which are generally classified as Level 1, are based on quoted prices in active markets. These securities represent actively and passively managed investments that are managed against various equity indices and exchange traded funds (ETFs) . Investments in commingled equity and debt funds ar e categorized as equity securities. Investments in commingled equity funds include funds that invest in U.S. and international equity securities. Investments in commingled debt funds include funds that invest in a diversified portfolio of emerging market debt obligations, as well as funds that invest in investment grade long-duration fixed-income securities. The fair value measurements of debt securities are generally based on evaluations that reflect observable market information, such as actual trade i nformation for identical securities or for similar securities, adjusted for observable differences. The fair value of d ebt securities is generally measured using a market approach, including the use of pricing models which incorporate observable inputs . Common inputs include benchmark yields, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates s imilar observable inputs as well as payment data, future predicted cash flows, collateral performance and new issue data. For the Master Trust, these

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2015
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	12. Jointly Owned Facilities ( PPL, LKE, LG&E and KU ) At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403 Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Sta tements of Income .
LG And E And KU Energy LLC [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	12. Jointly Owned Facilities ( PPL, LKE, LG&E and KU ) At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403 Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Sta tements of Income .
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	12. Jointly Owned Facilities ( PPL, LKE, LG&E and KU ) At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403 Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Sta tements of Income .
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	12. Jointly Owned Facilities ( PPL, LKE, LG&E and KU ) At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403 Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Sta tements of Income .

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies [Abstract]
Commitments and Contingencies	13 . Commitments and Contingencies (PPL) All commitments, contingencies and guarantees associated with PPL Energy Supply and its subsidiaries were retained by Talen Energy and its subsidiaries at the spinoff date without recourse to PPL. Energy Purchase Commitments (PPL , LKE, LG&E and KU ) LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E’s gas supply operations. These contracts include the following commitments: Maximum Maturity Contract Type Date Coal 2022 Coal Transportation and Fleeting Services 2024 Natural Gas Storage 2024 Natural Gas Transportation 2026 LG&E and KU have a power purchase agreement with OVEC expiring in June 2040. See footnote (f) to the table in "Guarantees and Other Assurances" below for information on the OVEC power purchase contract. Future obligations for power purchases from OVEC are unconditional demand payments, comprised of annual minimum debt service payments, as well as contractually required reimbursement of plant operating, maintenance and other expenses are projected as follows: LG&E KU Total 2016 $ 18 $ 8 $ 26 2017 19 8 27 2018 19 8 27 2019 19 9 28 2020 20 9 29 Thereafter 435 193 628 $ 530 $ 235 $ 765 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2015 2014 2013 LG&E $ 15 $ 17 $ 18 KU 7 8 8 Total $ 22 $ 25 $ 26 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 leg al proceedings. (PPL, LKE , LG&E and KU ) Cane Run Environmental Claims In December 2013, six residents, on behalf of themselves and others similarly situated, filed a class action complaint against LG&E and PPL in the U.S. District Court for the Western District of Kentucky 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 fee s, 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 plant. In their individual capacities, these plaintiffs seek 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 cl aim, but declined to dismiss their common law tort claims. Upon motion of LG&E and PPL, the district court certified for appellate review the issue of whether the state common law claims are preempted by federal statute. In December 2014, the U.S. Court of Appeals for the Sixth Circuit issued an order granting appellate review regarding the above matter. Oral argument before the Sixth Circuit was held in August 2 015. In November 2015, the Sixth Circuit issued an opinion affirming the District Court's ru ling that plaintiffs' state law claims are not preempted by the Clean Air Act and remanding the matter to the District Court for further proceedings. Certain discovery matters are currently before the District Court. 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. Mill Creek Environmental Claims In May 2014, the Sierra Club filed a citizen suit against LG &E in the U.S. District Court for the Western District of Kentucky for alleged violations of the Clean Water Act. The Sierra Club alleges that various discharges at the Mill Creek plant constitute violations of the plant's water discharge permit. The Sie rra Club seeks civil penalties, injunctive relief, costs and attorney's fees. In August 2015, the Court denied cross-motions for summary judgment filed by both parties and directed the parties to proceed with discovery . Discovery proceedings are underway and the parties have also conducted limited settlement discussions in the matter. PPL, LKE and LG&E cannot predict the outcome of this matter or the potential impact on the operations of the Mill Creek plant , including increased capital or operating costs, if any, but believe the plant is operating in compliance with the permits. E.W. Brown Environmental Claims In October 2015, KU received a notice of intent from Earthjustice and the Sierra Club informing certain federal and state agencies of the Sierra Club's intent to file a citizen suit, following expiration of the mandatory 60-day notification period, for alleged violations of the Clean Water Act. The claimant alleges dis charges at the E.W. Brown plant in violation of applicable rules and the plant's water discharge permit. The claimant asserts that, unless the alleged discharges are promptly brought into compliance, it intends to seek civil penalties, injunctive relief a nd attorney's fees. In November 2015, the claimants submitted an amended notice of intent to add the Kentucky Waterways Alliance as a claimant. The parties have conducted limited settlement discussions in the matter. PPL, LKE and KU cannot predict the o utcome of this matter or the potential impact on the operations of the E. W. Brown plant , including increased capital or operating costs, if any . Trimble County Unit 2 Air Permit The Sierra Club and other environmental groups petitioned the Kentucky En vironmental and Public Protection Cabinet to overturn the air permit issued for the Trimble County Unit 2 baseload coal-fired generating unit, but the agency upheld the permit in an order issued in September 2007. In response to subsequent petitions by en vironmental groups, the EPA ordered certain non-material changes to the permit which, in January 2010, were incorporated into a final revised permit issued by the Kentucky Division for Air Quality. In March 2010, the environmental groups petitioned the EP A to object to the revised state permit. Until the EPA issues a final ruling on the pending petition and all available appeals are exhausted, PPL, LKE, LG&E and KU cannot 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. 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 subsequ ently 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 Cou rt of Appeals. In July 2015, the Court of Appeals upheld the lower court ruling. LG&E and the KEEC have moved for discretionary review by the Kentucky Supreme Court. On February 10, 2016, the Kentucky Supreme Court issued an order granting discretionary review. 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. 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 power system. 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 power electricity system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties of up to $1 million per day, per violation, for certain violations. PPL, LG&E, KU and PPL Electric monitor their compliance with the Reliability Standards and continue to self-report or self-log potential violations of certain applicable reliability requirements and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. 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 - Domestic (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. 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-p roducts 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' respect ive state regulatory authorities, or the FERC, if applicable. Because PPL Electric does not own any generating plants, its 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. (PPL, LKE, LG&E and KU) Air The Clean Air Act, which regulates air pollutants from mobile and stationary sources, has a significant impact on the operation o f 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 p lan s, 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 implementing them , 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 currently anticipate significant co sts 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 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 2017. States are also obligated to address interstate transport issues associated with new o zone standards through the establishment of "good neighbor" state implementation plans for those states that are found to contribute significantly to another states' non-attainment. States that are not in the ozone transport region, including Kentucky, ar e working together to evaluate further nitrogen oxide reductions from fossil-fueled plants with SCRs. The nature and timing of any additional reductions resulting from these evaluations cannot be predicted at this time. 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 K entucky. Attainment must be achieved by 2018 . PPL, LKE, LG&E and KU anticipate that certain previously required compliance measures, such as upgraded or new sulfur dioxide scrubbers at certain plants and the retirement of coal-fired generating units at L G&E's Cane Run plant and KU's Green River plant, will help to achieve compliance with the new sulfur dioxide and ozone standards. If additional reductions are required, the costs could be significant. Mercury and Air Toxics Standards (MATS) In February 2012, the EPA finalized the MATS rule requiring reductions of mercury and other hazardous air pollutants from fossil-fuel fired power plants, with an effective date of April 16, 2012. The MATS rule was challenged by industry groups and states and was upheld by the U.S. Court of Appeals for the D. C. Circuit Court (D.C. Circuit Court) in April 2014. A group of states subsequently petitioned the U.S. Supreme Court (Supreme Cour t) to review this decision and i n June 2015, the Supreme Court held that the EPA failed to properly consider costs when deciding to regulate hazardous air emissions from power plants under MATS. The Court remanded the matter to the D.C. Circuit Court , which in December 2015 remanded the rule to EPA without vacating it. E PA has proposed a supplemental finding regarding costs of the rule and has announced that it intends to make a final determination in 2016. The EPA's MATS rule remains in effect during the pendency of the ongoing proceedings. LG&E and KU have installed significant controls in connection with the MATS rule and in conjunction with compliance with other environmental requirements, including fabric-filter baghouses , upgraded scrubber s or chemical additive systems for which appropriate KPSC authorization and/ or ECR treatment has been received. LG&E and KU are currently seeking KPSC approval for a compliance plan providing for installation of additional MATS-related controls, the cost of which is currently estimated at $ 5 million fo r LG&E and at $ 17 million for KU. PPL, LKE, LG&E and KU cannot predict the outcome of the MATS rule or its potential impact, if any, on plant operations, rate treatment or future capital or operating needs. See Note 6 for a dditional information. New Source Review (NSR) The NSR litigation brought by EPA, states and environmental groups against coal-fired generating plants in past years continues to proceed through the courts. Although none of this litigation directly invol ves PPL, LKE, LG&E or KU, it can influence the permitting of large capital projects at LG&E and KU’s power plants, the costs of which cannot presently be determined but could be significant. Climate Change (All Registrants) There is continuing momentum to address climate change. Most recently, i n 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 mai ntain GHG reduction commitments. Based on EPA’s Clean Power Plan described below, t he U.S. has committed to an initial reduct ion target of 26% to 28% below 2005 levels by 2025. The EPA's Rules under Section 111 of the Clean Air Act As further described below, the EPA finalized rules imposing greenhouse gas emission standards for both new and existing power plants. The EPA h as 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 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. On February 9, 2016, the 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 Sup reme Court if a writ of certiorari is filed and granted. 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 available, the rule effectively precludes the construction of new coal-fired plants. The standard for NGCC power plants is the sa me as 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 Clean Power Plan 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 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 a nd Kentucky fails to develop an approvable implementation plan by the applicable deadline, the EPA would 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 participating in the ongoing regulatory processes at the state and federal level in an effort to provide input into the state or federal implementation plan that will govern reductions in Kentucky. Various states, industry groups, and individual companies including LKE have filed petitions for reconsideration with EPA an d petitions for review with the D.C. Circuit Court challenging the Clean Power Plan . PPL, LKE, LG&E and KU cannot predict the outcome of this matter or the potential impact, if any, on plant operations, or future capital or operating needs. 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 which limits the measures that the Kentucky Energy and Environment Cabinet may consider in set ting performance standards to comply with the EPA's regulations governing GHG emissions from existing sources. The legislation provides that such state GHG performance standards shall be based on emission reductions, efficiency measures, and other improve ments 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 establi shed for Kentucky. Water/Waste Coal Combustion Residuals (CCRs) On April 17, 2015, the EPA published its final rule regulating CCRs. CCRs include fly ash, bottom ash and sulfur dioxide scru bber wastes. The rule beca me effective on October 1 9, 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 and not closed. Under the rule, the EPA will regulate CCRs as non-hazardous under Subtitle D of RCRA and allow beneficial use of CCRs, with some restrictions. The rule's requirements for covered CCR impoundments and la ndfills include implementation of groundwater monitoring and commencement or completion of closure activities generally between three and ten years from certain triggering events. This self-implementing rule requires posting of compliance documentation on a publicly accessible website and is enforceable solely through citizen suits. LG&E and KU are also subject to state rules applicable to CCR management which may potentially be modified to reflect some or all requirements of the federal rule. LG&E and K U are currently pursuing K PSC approval for a compliance plan providing for construction of additional landfill capacity at the Brown Station, closure of impoundments at the Mill Creek, Trimble County, Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required f or compliance with federal CCR r ule requirements, LG&E and KU are also proposing to close impoundments at the retired Green River, Pineville, and Tyrone plants to comply with applicable state law requirements. PPL, LKE, LG&E, and KU currently estimate the cost of these CCR compliance measures at $ 311 million for LG&E and $ 661 million for KU . See Note 6 for addi tional information. In connection with the final CCR rule, LG&E and KU recorded increases to existing AROs during 2015. See Note 19 for additional information. Further increases to AROs or changes to current capital plans or to 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 many of LG&E's and KU's construction projects. 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 by reducing capture i n the screens attached to cooling water intake structures (impingement) at generating facilities and the water volume brought into the facilities (entrainment). The requirements could impose significant costs which are subject to rate recovery. Effluent Limitations Guidelines (ELGs) On September 30, 2015, the EPA released its final effluent limitations guidelines for wastewater discharge permits for new and existing steam electric generating facilities. The rule provides strict technology-based discharg e 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 tech nologies 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 impleme ntation date for individual generating stations will be determined by the states on a case-by-case basis according to criteria provided by the EPA, but the requirements of the rule must be fully implem ented no later than 2023. It has not been decided how Kentucky intends to integrate the ELGs into its routine permit renewal process. LG&E and KU continue to assess the requirements of this complex rule to determine available compliance strategies. PPL, LKE, LG&E and KU are unable to fully estimate complian ce costs or timing at this time although certain preliminary estimates are included in current capital forecasts, for applicable periods. Costs to comply with ELGs or other discharge limits, which are expected to be significant, are subject to rate recove ry. (PPL, LKE and LG&E) Clean Water Act Section 316(b) The EPA's final 316(b) rule for existing facilities became effective in October 2014, and regulates cooling water intake structures and their impact on aquatic organisms. States are allowed br oad discretion to make site-specific determinations under the rule. The rule requires existing facilities to choose between several options to reduce the impact to aquatic organisms that become trapped against water intake screens (impingement) and to det ermine the intake structure's impact on aquatic organisms pulled through a plant's cooling water system (entrainment). Plants equipped with closed-cycle cooling, an acceptable option, would likely not incur substantial costs. Once-through systems would l ikely require additional technology to comply with the rule. Mill Creek Unit 1 is the only unit expected to be impacted. PPL, LKE, and LG&E are evaluating compliance strategies but do not presently expect the compliance costs, which are subject to rate r ecovery, to be significant. (All Registrants) Waters of the United States (WOTUS) T he U.S. Court of Appeals for the Sixth Circuit has issued a stay of EPA's rule on the definition of WOTUS pending the court's review of the rule. The effect of the stay is that the WOTUS rule is not currently in effect anywhere in the United States. The ultimate outcome of the court's review of the rule remains uncertain. The Registrants do not expect the rule to have a signific ant impact on their operations. Other Issues The EPA is reassessing its p olychlorinated biphenyls (PCB) regulations under the Toxic Substance Control Act, which currently allow certain PCB articles to remain in use. In April 2010, the EPA issued an Advanced Notice of Proposed Rulemaking for changes to these regulations. This rulemaking could lead to a phase-out of all or some PCB-containing equipment. The EPA has postponed the release of the revised regulations to March 2016. The Registrants cannot predict at this time the outcome of these proposed EPA regulations and what impact, if any, they woul d have on their facilities, but the costs could be significant. Superfund and Other Remediation (All Registrants) PPL Electric is potentially responsible for costs at several sites listed by the EPA under the federal Superfund program, including the Colu mbia Gas Plant site, the Metal Bank 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 significant to PPL Electric. Should the EPA require different or additional measure s in the future, however, or should PPL Electric's share of costs at multi-party sites increase substantially more than currently expected, the costs could be significant. PPL Electric, LG&E and KU are investigating, responding to agency inquiries, remedi ating, 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. LG&E and KU lack information on the conditions of 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 December 31, 2015, PPL Electric has accrued $10 million representing its best estimate of the probable loss incurred to remediate additional sites previously owned or operated by PPL Electric predecessors or affiliates . 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 , the costs of remediation and other liabilities could be significant and may be as muc h as $ 29 million. 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 f or 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 possi ble losses, if any, related to these matters. From time to time, PPL's subsidiaries undertake 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 lo cal agencies regarding actions necessary for compliance with applicable requirements, negotiate with property owners and other third parties alleging impacts from PPL's operations and undertake similar actions necessary to resolve environmental matters tha t arise in the course of normal operations. Based on analyses to date, resolution of these environmental matters is not expected to have a significant adverse impact on the operations of PPL Electric, LG&E and KU. Future cleanup or remediation work at si tes currently under review, or at sites not currently identified, may result in significant additional costs for PPL, PPL Electric, LKE, LG&E and KU. Insurance policies maintained by LKE, LG&E and KU may be applicable to certain of the costs or other obli gations related to these matters but the amount of insurance coverage or reimbursement cannot be estimated or assured. Environmental Matters - WPD (PPL ) WPD ' s distribution businesses are subject to environmental regulatory and statutory requirements. PPL believes that WPD has taken and continues to take measures to comply with the applicable laws and governmental regulations for the protection of the environment . Other Guarantees and Other Assurance

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	14. Related Party Transactions PLR Contracts/Purchase of Accounts Receivable ( PPL Electric) PPL Electric holds competitive solicitations for PLR generation supply. PPL EnergyPlus was awarded a portion of the PLR generation supply through these competitive solicitations. The purchases from PPL EnergyPlus are included in PPL Electric's Statements of Income as "Energy purchases from affiliate" through May 31, 2015, the period throug h which PPL Electric and PPL EnergyPlus were affiliated entities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL El ectric's purchases from Talen Energy Marketing subsequent to May 31, 2015 are included as purchases from an unaffiliated third party. Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all s uppliers to post collateral once credit exposures exceed defined credit limits. Wholesale suppliers are required to post collateral with PPL Electric when: (a) the market price of electricity to be delivered by the wholesale suppliers exceeds the contrac t price for the forecasted quantity of electricity to be delivered; and (b) this market price exposure exceeds a contractual credit limit. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts. PPL Electr ic's customers may choose an alternative supplier for their generation supply. See Note 1 for additional information regarding PPL Electric's purchases of accounts receivable from alternative suppliers, including Talen Energy Marketing. See Note 8 for additional information regarding the spinoff of PPL Energy Supply. Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers . When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E. When KU has excess generation capacity after serving its own retail customers and its generation cost is lower than that of LG&E, LG&E purchases electricity from KU. T hese transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings . Savings realized from such intercompany transactions are sh ared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. S upport Costs ( PPL Electric, LKE, LG&E and KU ) PPL Services and LKS provide PPL and LKE subsidiaries with administrative, management and support services . In 2015, PPL EU Services was formed to provide the majority of financial, supply chain, human resources and facilities management services primarily to PPL Electric. PPL Services will continue to provide certain corporate functions. For all service companies, the costs of these servic es are charged to the recipients as direct support costs. G ene ral costs that cannot be directly attributed to a specific entity are allocat ed and charged to the recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capi tal, 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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160 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 rei mbursed through LKS . Intercompany Borrowings (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 December 31, 2015 and 2014 , $ 54 million and $ 41 million, respectively, was outstanding and reflected in "Notes payable with affiliates" on the Ba lance Sheet. The interest rate on the outstanding borrowing at December 31, 2015 was 1.74% and 1.65% at December 31, 2014 . Interest expense on the revolving line of credit was not significant for 2015 , 2014 or 2013 . LKE maintains an agreement with a PPL affiliate that has a $ 300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstand ing at December 31, 2015 and 2014 . The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. Interest income on this note was not significant for 2015 , 2014 or 2013 . LKE entered into a $ 400 million ten-year-note with PPL Capital Funding in November 2015. The proceeds were used to pay off an LKE senior unsecured note of the same amount maturing in November 2015. The interest rate on the note is equal to 3.5% with interest payments due in May and November . At December 31, 2015 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheet. Interest expense on this note was not significant for 2015. Intercompany Derivatives ( LKE, LG&E and KU ) Periodically, LG&E and KU enter into forward-starting interest rate swaps with PPL . These hedging instruments have terms identical to forward-starting swaps entered into by PPL with third parties . See Note 17 for additional information on intercompany derivatives. Other ( PPL Electric, LKE, LG&E and KU ) See Note 1 f or discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). For PPL Electric, LG&E and KU, see Note 11 for discussions regarding intercompany allocations associated with defined benefits.
LG And E And KU Energy LLC [Member]
Related Party Transactions [Line Items]
Related Party Transactions	14. Related Party Transactions PLR Contracts/Purchase of Accounts Receivable ( PPL Electric) PPL Electric holds competitive solicitations for PLR generation supply. PPL EnergyPlus was awarded a portion of the PLR generation supply through these competitive solicitations. The purchases from PPL EnergyPlus are included in PPL Electric's Statements of Income as "Energy purchases from affiliate" through May 31, 2015, the period throug h which PPL Electric and PPL EnergyPlus were affiliated entities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL El ectric's purchases from Talen Energy Marketing subsequent to May 31, 2015 are included as purchases from an unaffiliated third party. Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all s uppliers to post collateral once credit exposures exceed defined credit limits. Wholesale suppliers are required to post collateral with PPL Electric when: (a) the market price of electricity to be delivered by the wholesale suppliers exceeds the contrac t price for the forecasted quantity of electricity to be delivered; and (b) this market price exposure exceeds a contractual credit limit. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts. PPL Electr ic's customers may choose an alternative supplier for their generation supply. See Note 1 for additional information regarding PPL Electric's purchases of accounts receivable from alternative suppliers, including Talen Energy Marketing. See Note 8 for additional information regarding the spinoff of PPL Energy Supply. Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers . When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E. When KU has excess generation capacity after serving its own retail customers and its generation cost is lower than that of LG&E, LG&E purchases electricity from KU. T hese transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings . Savings realized from such intercompany transactions are sh ared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. S upport Costs ( PPL Electric, LKE, LG&E and KU ) PPL Services and LKS provide PPL and LKE subsidiaries with administrative, management and support services . In 2015, PPL EU Services was formed to provide the majority of financial, supply chain, human resources and facilities management services primarily to PPL Electric. PPL Services will continue to provide certain corporate functions. For all service companies, the costs of these servic es are charged to the recipients as direct support costs. G ene ral costs that cannot be directly attributed to a specific entity are allocat ed and charged to the recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capi tal, 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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160 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 rei mbursed through LKS . Intercompany Borrowings (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 December 31, 2015 and 2014 , $ 54 million and $ 41 million, respectively, was outstanding and reflected in "Notes payable with affiliates" on the Ba lance Sheet. The interest rate on the outstanding borrowing at December 31, 2015 was 1.74% and 1.65% at December 31, 2014 . Interest expense on the revolving line of credit was not significant for 2015 , 2014 or 2013 . LKE maintains an agreement with a PPL affiliate that has a $ 300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstand ing at December 31, 2015 and 2014 . The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. Interest income on this note was not significant for 2015 , 2014 or 2013 . LKE entered into a $ 400 million ten-year-note with PPL Capital Funding in November 2015. The proceeds were used to pay off an LKE senior unsecured note of the same amount maturing in November 2015. The interest rate on the note is equal to 3.5% with interest payments due in May and November . At December 31, 2015 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheet. Interest expense on this note was not significant for 2015. Intercompany Derivatives ( LKE, LG&E and KU ) Periodically, LG&E and KU enter into forward-starting interest rate swaps with PPL . These hedging instruments have terms identical to forward-starting swaps entered into by PPL with third parties . See Note 17 for additional information on intercompany derivatives. Other ( PPL Electric, LKE, LG&E and KU ) See Note 1 f or discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). For PPL Electric, LG&E and KU, see Note 11 for discussions regarding intercompany allocations associated with defined benefits.
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	14. Related Party Transactions PLR Contracts/Purchase of Accounts Receivable ( PPL Electric) PPL Electric holds competitive solicitations for PLR generation supply. PPL EnergyPlus was awarded a portion of the PLR generation supply through these competitive solicitations. The purchases from PPL EnergyPlus are included in PPL Electric's Statements of Income as "Energy purchases from affiliate" through May 31, 2015, the period throug h which PPL Electric and PPL EnergyPlus were affiliated entities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL El ectric's purchases from Talen Energy Marketing subsequent to May 31, 2015 are included as purchases from an unaffiliated third party. Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all s uppliers to post collateral once credit exposures exceed defined credit limits. Wholesale suppliers are required to post collateral with PPL Electric when: (a) the market price of electricity to be delivered by the wholesale suppliers exceeds the contrac t price for the forecasted quantity of electricity to be delivered; and (b) this market price exposure exceeds a contractual credit limit. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts. PPL Electr ic's customers may choose an alternative supplier for their generation supply. See Note 1 for additional information regarding PPL Electric's purchases of accounts receivable from alternative suppliers, including Talen Energy Marketing. See Note 8 for additional information regarding the spinoff of PPL Energy Supply. Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers . When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E. When KU has excess generation capacity after serving its own retail customers and its generation cost is lower than that of LG&E, LG&E purchases electricity from KU. T hese transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings . Savings realized from such intercompany transactions are sh ared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. S upport Costs ( PPL Electric, LKE, LG&E and KU ) PPL Services and LKS provide PPL and LKE subsidiaries with administrative, management and support services . In 2015, PPL EU Services was formed to provide the majority of financial, supply chain, human resources and facilities management services primarily to PPL Electric. PPL Services will continue to provide certain corporate functions. For all service companies, the costs of these servic es are charged to the recipients as direct support costs. G ene ral costs that cannot be directly attributed to a specific entity are allocat ed and charged to the recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capi tal, 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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160 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 rei mbursed through LKS . Intercompany Borrowings (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 December 31, 2015 and 2014 , $ 54 million and $ 41 million, respectively, was outstanding and reflected in "Notes payable with affiliates" on the Ba lance Sheet. The interest rate on the outstanding borrowing at December 31, 2015 was 1.74% and 1.65% at December 31, 2014 . Interest expense on the revolving line of credit was not significant for 2015 , 2014 or 2013 . LKE maintains an agreement with a PPL affiliate that has a $ 300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstand ing at December 31, 2015 and 2014 . The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. Interest income on this note was not significant for 2015 , 2014 or 2013 . LKE entered into a $ 400 million ten-year-note with PPL Capital Funding in November 2015. The proceeds were used to pay off an LKE senior unsecured note of the same amount maturing in November 2015. The interest rate on the note is equal to 3.5% with interest payments due in May and November . At December 31, 2015 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheet. Interest expense on this note was not significant for 2015. Intercompany Derivatives ( LKE, LG&E and KU ) Periodically, LG&E and KU enter into forward-starting interest rate swaps with PPL . These hedging instruments have terms identical to forward-starting swaps entered into by PPL with third parties . See Note 17 for additional information on intercompany derivatives. Other ( PPL Electric, LKE, LG&E and KU ) See Note 1 f or discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). For PPL Electric, LG&E and KU, see Note 11 for discussions regarding intercompany allocations associated with defined benefits.
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	14. Related Party Transactions PLR Contracts/Purchase of Accounts Receivable ( PPL Electric) PPL Electric holds competitive solicitations for PLR generation supply. PPL EnergyPlus was awarded a portion of the PLR generation supply through these competitive solicitations. The purchases from PPL EnergyPlus are included in PPL Electric's Statements of Income as "Energy purchases from affiliate" through May 31, 2015, the period throug h which PPL Electric and PPL EnergyPlus were affiliated entities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL El ectric's purchases from Talen Energy Marketing subsequent to May 31, 2015 are included as purchases from an unaffiliated third party. Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all s uppliers to post collateral once credit exposures exceed defined credit limits. Wholesale suppliers are required to post collateral with PPL Electric when: (a) the market price of electricity to be delivered by the wholesale suppliers exceeds the contrac t price for the forecasted quantity of electricity to be delivered; and (b) this market price exposure exceeds a contractual credit limit. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts. PPL Electr ic's customers may choose an alternative supplier for their generation supply. See Note 1 for additional information regarding PPL Electric's purchases of accounts receivable from alternative suppliers, including Talen Energy Marketing. See Note 8 for additional information regarding the spinoff of PPL Energy Supply. Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers . When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E. When KU has excess generation capacity after serving its own retail customers and its generation cost is lower than that of LG&E, LG&E purchases electricity from KU. T hese transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings . Savings realized from such intercompany transactions are sh ared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. S upport Costs ( PPL Electric, LKE, LG&E and KU ) PPL Services and LKS provide PPL and LKE subsidiaries with administrative, management and support services . In 2015, PPL EU Services was formed to provide the majority of financial, supply chain, human resources and facilities management services primarily to PPL Electric. PPL Services will continue to provide certain corporate functions. For all service companies, the costs of these servic es are charged to the recipients as direct support costs. G ene ral costs that cannot be directly attributed to a specific entity are allocat ed and charged to the recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capi tal, 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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160 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 rei mbursed through LKS . Intercompany Borrowings (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 December 31, 2015 and 2014 , $ 54 million and $ 41 million, respectively, was outstanding and reflected in "Notes payable with affiliates" on the Ba lance Sheet. The interest rate on the outstanding borrowing at December 31, 2015 was 1.74% and 1.65% at December 31, 2014 . Interest expense on the revolving line of credit was not significant for 2015 , 2014 or 2013 . LKE maintains an agreement with a PPL affiliate that has a $ 300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstand ing at December 31, 2015 and 2014 . The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. Interest income on this note was not significant for 2015 , 2014 or 2013 . LKE entered into a $ 400 million ten-year-note with PPL Capital Funding in November 2015. The proceeds were used to pay off an LKE senior unsecured note of the same amount maturing in November 2015. The interest rate on the note is equal to 3.5% with interest payments due in May and November . At December 31, 2015 , the note was reflected in "Long-term debt to affiliate" on the Balance Sheet. Interest expense on this note was not significant for 2015. Intercompany Derivatives ( LKE, LG&E and KU ) Periodically, LG&E and KU enter into forward-starting interest rate swaps with PPL . These hedging instruments have terms identical to forward-starting swaps entered into by PPL with third parties . See Note 17 for additional information on intercompany derivatives. Other ( PPL Electric, LKE, LG&E and KU ) See Note 1 f or discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). For PPL Electric, LG&E and KU, see Note 11 for discussions regarding intercompany allocations associated with defined benefits.

Other Income (Expense) - net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2015
Other Income (Expense) - net [Abstract]
Other Income (Expense) - net	15. Other Income (Expense) - net (PPL) The breakdown of "Other Income (Expense) - net" for the years ended December 31 was: PPL 2015 2014 2013 Other Income Interest income $ 4 $ 1 AFUDC - equity component 14 11 $ 10 Miscellaneous 6 7 4 Total Other Income 24 19 14 Other Expense Economic foreign currency exchange contracts (Note 17) (122) (121) 38 Charitable contributions 21 27 21 Miscellaneous 17 8 10 Total Other Expense (84) (86) 69 Other Income (Expense) - net $ 108 $ 105 $ (55)

Fair Value Measurements and Cre

Fair Value Measurements and Credit Concentration	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements and Credit Concentration [Abstract]
Fair Value Measurements and Credit Concentration	16. 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 a n 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 a sset 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 2015 and 2014 , there were no transfers between Level 1 and Level 2. See Note 1 for information on the levels in the fair value hierarchy. Recurring Fair Value Measurements The a ssets and liabilities measured at fair value were: December 31, 2015 December 31, 2014 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 836 $ 836 $ 1,399 $ 1,399 Short-term investments 120 120 Restricted cash and cash equivalents (a) 33 33 31 31 Price risk management assets (b): Foreign currency contracts 209 $ 209 130 $ 130 Cross-currency swaps 86 86 29 28 $ 1 Total price risk management assets 295 295 159 158 1 Auction rate securities (c) 2 $ 2 2 2 Total assets $ 1,166 $ 869 $ 295 $ 2 $ 1,711 $ 1,550 $ 158 $ 3 Liabilities Price risk management liabilities (b): Interest rate swaps $ 71 $ 71 $ 156 $ 156 Foreign currency contracts 1 1 2 2 Cross-currency swaps 3 3 Total price risk management liabilities $ 72 $ 72 $ 161 $ 161 PPL Electric Assets Cash and cash equivalents $ 47 $ 47 $ 214 $ 214 Restricted cash and cash equivalents (a) 2 2 3 3 Total assets $ 49 $ 49 $ 217 $ 217 LKE Assets Cash and cash equivalents $ 30 $ 30 $ 21 $ 21 Cash collateral posted to counterparties (d) 9 9 21 21 Total assets $ 39 $ 39 $ 42 $ 42 Liabilities Price risk management liabilities: Interest rate swaps $ 47 $ 47 $ 114 $ 114 Total price risk management liabilities $ 47 $ 47 $ 114 $ 114 LG&E Assets Cash and cash equivalents $ 19 $ 19 $ 10 $ 10 Cash collateral posted to counterparties (d) 9 9 21 21 Total assets $ 28 $ 28 $ 31 $ 31 Liabilities Price risk management liabilities: Interest rate swaps $ 47 $ 47 $ 81 $ 81 Total price risk management liabilities $ 47 $ 47 $ 81 $ 81 KU Assets Cash and cash equivalents $ 11 $ 11 $ 11 $ 11 Total assets $ 11 $ 11 $ 11 $ 11 Liabilities Price risk management liabilities: Interest rate swaps $ 33 $ 33 Total price risk management liabilities $ 33 $ 33 (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) Included in "Price risk management assets ", "Other current liabilities", "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (c) I ncluded in "Other current assets" on the Balance Sheets. (d) Included in "Other non current 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 exchange risk, PPL use s foreign currency contracts s uch as forwards, options, and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. A n 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 obtain ed to value credit risk and therefore internal models are relied upon . These models use projected probabili ties of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contra cts are classified as Level 3. Nonrecurring Fair Value Measurement s See Note 8 for information regarding the estimated fair value of the Supply segment’s net assets as of the June 1, 2015 spinoff date . Financial Instruments Not Recorded at Fair Value ( All Registrants ) The carrying amounts of long-term debt on the Balance Sheets and their estimated fair value s are set forth below , excluding long-term debt of discontinued operations at December 31, 2014. The fair value s 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-pa rty credit enhancements is not included in the fair value measurement. December 31, 2015 December 31, 2014 Carrying Carrying Amount Fair Value Amount Fair Value PPL $ 19,048 $ 21,218 $ 18,054 $ 20,466 PPL Electric 2,828 3,088 2,581 2,990 LKE 5,088 5,384 4,543 4,946 LG&E 1,642 1,704 1,345 1,455 KU 2,326 2,467 2,079 2,313 The carrying value of short-term debt (including notes between affiliates), when outstanding, approximates fair value due to the variable interest rates associated with the short-term debt and is classified as Level 2.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities [Abstract]
Derivative Instruments and Hedging Activities	17. 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 b y the Chief Risk Officer, 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 a nd 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, volumes of f ull-requirement sales contracts, 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 followi ng summarizes the market risks that affect PPL and its s ubsidiar ies . 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. LG&E utilizes over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utiliz e 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 b enefit 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  P PL 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. WPD is expo sed to v olumetric risk which is significantly mitigated as a result of the method of regulation in the U.K.  PPL Electric is exposed to commodity price risk from its obligation as PLR; however, its PUC-approved cost recovery mechanism substantially elimi nates its exposure to this risk. PPL Electric also mitigates its exposure to volumetric risk by entering into full-requirement supply agreements to serve its PLR customers. These supply agreements transfer the volumetric risk associated with the PLR obli gation to the energy suppliers.  LG&E's and KU's rates include c ertain mechanisms for fuel and fuel-related expenses. In addition, LG&E's rates include certain mechanisms for natural gas supply. These mechanisms generally provide for timely recovery of market price and volumetric fluctuations associated with these expenses. Equity securities price risk  PPL and its subsidiaries are exposed to equity securities price risk associated with defined benefit plans. 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 throug h certain of its subsidiaries, as discussed below. In the event a supplier of LKE (through its subsidiaries LG&E and KU) or PPL Electric defaults on its obligation, those entities would be required to seek replacement power or replacement fuel in the mark et. 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 a nd 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 gener ally 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 i nvestment 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 ca sh collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. PPL, LKE, LG&E and KU had no obligation to return cash collateral under master netting arrangements at December 31, 2015 and 2014 . PPL, LKE and LG&E posted $ 9 million and $ 21 million of cash collateral under master netting arrangements at December 31, 2015 and 2014 . KU did not post any cash collateral under master netting arrangements at December 31, 2015 and 2014 . 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. V arious 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 p rogram 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. Cash Flow Hedges (PPL) Interest rate risks include exposure to adverse intere st rate movements for outstanding variable rate debt and for future anticipated financings. F inancial 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 December 31, 2015 , PPL held an aggregate notional value in interest rate swap contracts of $ 300 million that range in maturity through 2026 . At December 31, 2015 , PPL held an aggregate notional value in cross-currency interest rate swap contracts of $ 1.3 billion that range in maturity from 2016 through 2028 to hedge the interest paym ents and principal of WPD's U.S. dollar-denominated senior notes. For 2015 , 2014 and 2013 , hedge ineffectiveness associated with interest rate derivatives was insignificant. Cash flow hedges are discontinued if it is no lo nger probable that the original forecasted transaction will occur by the end of the o riginally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probabl e of occurring. As a result of the June 1, 2015 spinoff of PPL Energy Supply, all PPL cash flow hedges associated with PPL Energy Supply were ineffective and discontinued and therefore, reclassified into earnings during the second quarter of 2015 and refl ected in discontinued operations for 2015. See Note 8 for additional information. For PPL's remaining cash flow hedges, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedg es in 2015 and 2013 and an insignificant amount reclassified into earnings associated with discontinued cash flow hedges in 2014 . At December 31, 2015 , the accumulated net unre cognized after-tax gains ( losses ) on qualifying derivatives that ar e expected to be reclassified into earnings during the next 12 months were insignificant . Amounts are reclassified as the hedged interest expense is recorded . ( LKE, LG&E and KU ) Periodically, LG&E and KU enter into forward-starting interest rate swaps with PPL that have terms identical to forward-starting swaps entered into by PPL with third parties. It is probable that realized gains and losses on all of these swaps will be recoverable through regulated rates; as such, any gains and losses on these derivatives are included in regulatory assets or liabilities and will be recognized in “Interest Expense” on the Statements of Income over the life of the under lying debt at the time the underlying hedged interest expense is recorded. In September 2015, first mortgage bonds totaling $ 1.05 billion were issued (LG&E issued $ 550 million and KU issued $ 500 million) and all outstanding forward-starting interest rate swaps were terminated. Net cash settlements of $ 88 million were paid on the swaps that were terminated (LG&E and KU each paid $ 44 million). The settlements are included in "Regulatory assets" (noncurrent) on the Balance Sheets and "Cash Flows from Operating Activities" on the Statements of Cash Flows. 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 r ealized gains and losses from the swaps, including a terminated swap contract, 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. R ealized gains and losses are recognized in "Interest Expense " on the Statements of Income at the time the underlying hedged interest expense is recorded . At December 31, 2015 , LG&E held contracts with a notional amount of $ 179 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 in struments 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. The contr acts outstanding at December 31, 2015 had a notional amount of £ 50 million (approximately $ 84 million based on contracted rates). The settlement dates of these contracts range from May 2016 through June 2016 . At December 31, 2015 and 2014 , PPL had $ 19 million and $ 14 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 anticipate d earnings . At December 31, 2015 , the total exposure hedged by PPL was approximately £ 1.8 billion (approximately $ 2.9 billion based on contracted rates). These contracts h ad termination dates ranging from January 2016 through December 2017 . 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. Change s in the fair value of derivatives not designated as NPNS are recognized currently in earnings unless specific hedge accounting criteria are met and designated as such , except for the change s in fair value s of LG&E's and KU's interest rate swaps that are r ec ognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at December 31, 2015 and 2014 . See Note 1 for additional information on accounting policies related to derivative instruments. (PPL) The following table present s th e fair value and location of derivative instruments recorded on the Balance Sheets, excluding derivative instruments of discontinued operations . December 31, 2015 December 31, 2014 Derivatives designated as Derivatives not designated Derivatives designated as Derivatives not designated hedging instruments as hedging instruments hedging instruments as hedging instruments Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ 24 $ 5 $ 94 $ 5 Cross-currency swaps (b) $ 35 3 Foreign currency contracts 10 $ 94 1 $ 12 $ 67 Total current 45 24 94 6 12 97 67 5 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) 42 14 43 Cross-currency swaps (b) 51 29 Foreign currency contracts 105 5 46 2 Total noncurrent 51 105 42 34 14 46 45 Total derivatives $ 96 $ 24 $ 199 $ 48 $ 46 $ 111 $ 113 $ 50 ( a ) Included in "'Price r isk m anagement a ssets" of Current Assets, "Other current liabilities", "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheet s. (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 . Gain (Loss) Recognized in Income on Derivative Derivative Gain Location of Gain (Loss) Gain (Loss) Reclassified (Ineffective Portion and Derivative (Loss) Recognized in Recognized in Income from AOCI into Income Amount Excluded from Relationships OCI (Effective Portion) on Derivative (Effective Portion) Effectiveness Testing) 2015 Cash Flow Hedges: Interest rate swaps $ (34) Interest Expense $ (11) Discontinued operations $ (77) Cross-currency swaps 60 Other Income (Expense) - net 49 Interest Expense 2 Commodity contracts Discontinued operations 13 7 Total $ 26 $ 53 $ (70) Net Investment Hedges: Foreign currency contracts $ 9 2014 Cash Flow Hedges: Interest rate swaps $ (91) Interest Expense $ (18) $ 2 Cross-currency swaps 58 Other Income (Expense) - net 57 Interest Expense 4 Commodity contracts Discontinued operations 42 Total $ (33) $ 85 $ 2 Net Investment Hedges: Foreign currency contracts $ 23 2013 Cash Flow Hedges: Interest rate swaps $ 127 Interest Expense $ (20) Cross-currency swaps (41) Other Income (Expense) - net (28) Interest Expense 1 Commodity contracts Discontinued operations 210 $ 1 Total $ 86 $ 163 $ 1 Net Investment Hedges: Foreign currency contracts $ (14) Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative 2015 2014 2013 Foreign currency contracts Other Income (Expense) - net $ 122 $ 121 $ (38) Interest rate swaps Interest Expense (8) (8) (8) Total $ 114 $ 113 $ (46) Derivatives Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ (22) $ (66) Regulatory liabilities - noncurrent $ 72 Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ 1 $ (12) $ 22 (LK E) The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges. December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 66 (a) Represents the location on the Balance Sheet. The following table present s the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets and liabilities . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ (22) $ (66) Regulatory liabilities - noncurrent $ 72 (LG&E) The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges. December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 33 (a) Represents the location on the balance sheet. The following table present s the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets and liabilities . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory asset - noncurrent $ (11) $ (33) Regulatory liabilities - noncurrent $ 36 ( KU ) The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges . December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 33 (a) Represents the location on the Balance S heet s . The following table present s the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets and liabilities . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ (11) $ (33) Regulatory liabilities - noncurrent $ 36 (L KE and LG&E ) The following table present s th e fair value and the location on the Balance Sheets of derivative s not designated as hedging instruments . December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 5 $ 5 Total current 5 5 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps 42 43 Total noncurrent 42 43 Total derivatives $ 47 $ 48 (a) Represents the location on the Balance Sheet s . The following table s present the pre-tax effect of derivative s not designated as cash flow hedges that are recognized in income or regulatory assets . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Interest Expense $ (8) $ (8) $ (8) Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ 1 $ (12) $ 22 ( 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 li abilities 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 derivativ e 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 Cash Cash Derivative Collateral Derivative Collateral Gross Instruments Received Net Gross Instruments Pledged Net December 31, 2015 Treasury Derivatives PPL $ 295 $ 25 $ 270 $ 72 $ 25 $ 9 $ 38 LKE 47 9 38 LG&E 47 9 38 December 31, 2014 Treasury Derivatives PPL $ 159 $ 65 $ 94 $ 161 $ 65 $ 21 $ 75 LKE 114 20 94 LG&E 81 20 61 KU 33 33 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 addi tional 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 fe atures 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-rela ted 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 tra nsfer 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 payme nt or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features. ( PPL , LKE and LG&E ) At December 31, 2015 , 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 $ 28 $ 28 $ 28 Aggregate fair value of collateral posted on these derivative instruments 9 9 9 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 19 19 19 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2015
Goodwill and Other Intangible Assets [Abstract]
Goodwill and Other Intangible Assets	18. Goodwill and Other Intangible Assets Goodwill (PPL) The changes in the carrying amount of goodwill by segment were: U.K. Regulated Kentucky Regulated Total 2015 2014 2015 2014 2015 2014 Balance at beginning of period (a) $ 3,005 $ 3,143 $ 662 $ 662 $ 3,667 $ 3,805 Effect of foreign currency exchange rates (117) (138) (117) (138) Balance at end of period (a) $ 2,888 $ 3,005 $ 662 $ 662 $ 3,550 $ 3,667 (a ) There were no accumulated impairment losses related to goodwill. Other Intangible Assets (PPL) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Contracts (a) $ 407 $ 300 $ 408 $ 250 Land and transmission rights 337 111 329 108 Emission allowances/RECs (b) 5 5 Licenses and other 10 5 10 5 Total subject to amortization 759 416 752 363 Not subject to amortization due to indefinite life: Land and transmission rights 33 29 Easements (c) 303 250 Total not subject to amortization due to indefinite life 336 279 Total $ 1,095 $ 416 $ 1,031 $ 363 (a) Gross carrying amount includes the fair value at the acquisition date of the OVEC power purchase contract and coal contracts with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL. Offsetting regulatory liabilities were recorded related to these contracts, which are being amortized over the same period as the intangible assets, eliminating any income statement impact. This is referred to as "regulatory offset" in the tables below. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization. (c) Primarily from an increase in easements at WPD. Current intangible assets are in cluded in "Other current assets" and long-term intangible assets are included in "Other intangibles" on the Balance Sheets. Amortization Expense was as follows: 2015 2014 2013 Intangible assets with no regulatory offset $ 6 $ 6 $ 6 Intangible assets with regulatory offset 51 47 51 Total $ 57 $ 53 $ 57 Amortization expense for each of the next five years, excluding insignificant amounts for consumption of emission allowances/RECs, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with no regulatory offset $ 6 $ 6 $ 6 $ 6 $ 6 Intangible assets with regulatory offset 27 9 9 9 8 Total $ 33 $ 15 $ 15 $ 15 $ 14 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Land and transmission rights $ 316 $ 108 $ 308 $ 105 Licenses and other 4 1 4 1 Total subject to amortization 320 109 312 106 Not subject to amortization due to indefinite life: Land and transmission rights 33 29 Total $ 353 $ 109 $ 341 $ 106 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was insignificant in 2015 , 2014 and 2013 a nd is expected to be insignificant in future years . (LKE) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Coal contracts (a) $ 269 $ 252 $ 269 $ 210 Land and transmission rights 21 2 21 2 Emission allowances (b) 3 3 OVEC power purchase agreement (c) 126 42 126 33 Total subject to amortization $ 419 $ 296 $ 419 $ 245 (a) Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL . An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization. (c) Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional inf ormation. Current intangible assets are included in "Other current assets" on the Balance Sheets. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2015 2014 2013 Intangible assets with no regulatory offset $ 1 Intangible assets with regulatory offset $ 51 $ 47 51 Total $ 51 $ 47 $ 52 Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with regulatory offset $ 27 $ 9 $ 9 $ 9 $ 8 (LG&E) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Coal contracts (a) $ 124 $ 116 $ 124 $ 98 Land and transmission rights 7 1 7 1 Emission allowances (b) 1 1 OVEC power purchase agreement (c) 87 29 87 23 Total subject to amortization $ 219 $ 146 $ 219 $ 122 (a) Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there i s no accumulated amortization. (c) Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL . An offsetting regulatory liability was reco rded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional information. Current intangible assets are included in "Othe r current assets" on the Balance Sheets. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2015 2014 2013 Intangible assets with regulatory offset $ 24 $ 23 $ 23 Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with regulatory offset $ 14 $ 6 $ 6 $ 6 $ 6 (KU) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Coal contracts (a) $ 145 $ 136 $ 145 $ 112 Land and transmission rights 14 1 14 1 Emission allowances (b) 2 2 OVEC power purchase agreement (c) 39 13 39 10 Total subject to amortization $ 200 $ 150 $ 200 $ 123 (a) Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there i s no accumulated amortization. (c) Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was r ecorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional information. Current intangible assets are included in "Other current assets" on the Balance Sheets. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2015 2014 2013 Intangible assets with no regulatory offset $ 1 Intangible assets with regulatory offset $ 27 $ 24 28 Total $ 27 $ 24 $ 29 Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with regulatory offset $ 13 $ 3 $ 3 $ 3 $ 2

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	19. Asset Retirement Obligations (PPL) WPD has recorded conditional AROs required by U.K. law related to treated wood poles, gas-filled switchgear and fluid-filled cables. (PPL and PPL Electric) PPL Electric has identified legal retirement obligations for the retirement of certain transmission assets that could not be reasonably estimated due to indeterminable settlement dates. These assets are located on rights-of-way that allow the grantor to require PPL Electric to relocate or remove the assets. Since this option is at the discretion of the grantor of the right-of-way, PPL Electric is unable to determine when these events may occur. (PPL, LKE, LG&E and KU) LG&E's and KU's AROs are primarily related to the final retirement of assets as sociated with generating units. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements which do not generally require restoration upon re moval of the property. Therefore, no material AROs are recorded for transmission and distribution assets. As described in Notes 1 and 6 , LG&E's and KU's accretion and depreciation expense are recorded as a regulatory asset , such that there is no earnings impact. The changes in the carryin g amounts of AROs were as follows. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 ARO at beginning of period $ 336 $ 301 $ 285 $ 252 $ 74 $ 74 $ 211 $ 178 Accretion 19 16 18 14 5 4 13 10 Obligations incurred 5 1 5 1 3 2 1 Changes in estimated cash flow or settlement date 235 25 234 23 98 1 136 22 Effect of foreign currency exchange rates (2) (2) Obligations settled (7) (5) (7) (5) (5) (5) (2) ARO at end of period $ 586 $ 336 $ 535 $ 285 $ 175 $ 74 $ 360 $ 211 LKE recorded increases of $ 228 million ($ 139 million at KU and $ 89 million at LG&E) to the existing AROs during 2015 as a result of an engineering study that was performed, in connection with the final CCR rule, providing clarity on projected CCR closure costs and revisions in the timing and amounts of future expected cash flows. Further increases to AROs or changes to current capital plans or to operating costs may be required as estimates of future cash flows are refined based on closure developments, groundwater monitoring results and regulatory or legal proceedings. In 2014 , AROs w ere revalued primarily due to updates in the estimated cash flows for ash ponds based on updated cost estimates. As of December 31, 2015, LKE had $ 50 million ($ 25 million at LG&E and KU) of the ARO balance s classified as current liabilities. These current liabilities are primarily related to CCR closure costs expected to be incurred in 2016. As of December 31, 2014, s ubstantially all of the ARO balances are classified as noncurrent liabilities. See Note 13 for information on the final CCR rule and Note 6 for information on the rate recovery applications with the KPSC.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	20 . Accumulated Other Comprehensive Income (Loss) ( PPL and LKE ) The after-tax changes in AOCI by component for the years ended December 31 were as follows. Unrealized gains (losses) Defined benefit plans Foreign currency Available- Equity Prior Actuarial translation for-sale Qualifying investees' service gain adjustments securities derivatives AOCI costs (loss) Total PPL December 31, 2012 $ (149) $ 111 $ 132 $ 1 $ (14) $ (2,021) $ (1,940) Amounts arising during the year 138 67 45 2 71 323 Reclassifications from AOCI (6) (83) 6 135 52 Net OCI during the year 138 61 (38) 8 206 375 December 31, 2013 $ (11) $ 172 $ 94 $ 1 $ (6) $ (1,815) $ (1,565) Amounts arising during the year (275) 35 (10) 5 (509) (754) Reclassifications from AOCI (6) (64) 4 111 45 Net OCI during the year (275) 29 (74) 9 (398) (709) December 31, 2014 $ (286) $ 201 $ 20 $ 1 $ 3 $ (2,213) $ (2,274) Amounts arising during the year (234) 8 26 (9) (366) (575) Reclassifications from AOCI (2) 2 (1) 146 145 Net OCI during the year (234) 6 28 (1) (9) (220) (430) Distribution of PPL Energy Supply (See Note 8) (207) (55) 238 (24) December 31, 2015 $ (520) $ $ (7) $ $ (6) $ (2,195) $ (2,728) LKE December 31, 2012 $ 1 $ (2) $ (14) $ (15) Amounts arising during the year 28 28 Net OCI during the year 28 28 December 31, 2013 $ 1 $ (2) $ 14 $ 13 Amounts arising during the year (7) (50) (57) Reclassifications from AOCI (1) 1 (1) (1) Net OCI during the year (1) (6) (51) (58) December 31, 2014 $ $ (8) $ (37) $ (45) Amounts arising during the year (3) (4) (7) Reclassifications from AOCI 1 5 6 Net OCI during the year (2) 1 (1) December 31, 2015 $ $ (10) $ (36) $ (46) The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2015 and 2014 . The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization . See Note 11 for additional information. PPL Affected Line Item on the Details about AOCI 2015 2014 Statements of Income Available-for-sale securities $ 4 $ 13 Other Income (Expense) - net Total Pre-tax 4 13 Income Taxes (2) (7) Total After-tax 2 6 Qualifying derivatives Interest rate swaps (11) (16) Interest Expense (77) Discontinued operations Cross-currency swaps 49 57 Other Income (Expense) - net 2 4 Interest Expense Commodity contracts 20 42 Discontinued operations Total Pre-tax (17) 87 Income Taxes 15 (23) Total After-tax (2) 64 Equity Investees' AOCI 1 Other Income (Expense) - net Total Pre-tax 1 Income Taxes Total After-tax 1 Defined benefit plans Prior service costs (7) Net actuarial loss (192) (145) Total Pre-tax (192) (152) Income Taxes 46 37 Total After-tax (146) (115) Total reclassifications during the year $ (145) $ (45)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	20 . Accumulated Other Comprehensive Income (Loss) ( PPL and LKE ) The after-tax changes in AOCI by component for the years ended December 31 were as follows. Unrealized gains (losses) Defined benefit plans Foreign currency Available- Equity Prior Actuarial translation for-sale Qualifying investees' service gain adjustments securities derivatives AOCI costs (loss) Total PPL December 31, 2012 $ (149) $ 111 $ 132 $ 1 $ (14) $ (2,021) $ (1,940) Amounts arising during the year 138 67 45 2 71 323 Reclassifications from AOCI (6) (83) 6 135 52 Net OCI during the year 138 61 (38) 8 206 375 December 31, 2013 $ (11) $ 172 $ 94 $ 1 $ (6) $ (1,815) $ (1,565) Amounts arising during the year (275) 35 (10) 5 (509) (754) Reclassifications from AOCI (6) (64) 4 111 45 Net OCI during the year (275) 29 (74) 9 (398) (709) December 31, 2014 $ (286) $ 201 $ 20 $ 1 $ 3 $ (2,213) $ (2,274) Amounts arising during the year (234) 8 26 (9) (366) (575) Reclassifications from AOCI (2) 2 (1) 146 145 Net OCI during the year (234) 6 28 (1) (9) (220) (430) Distribution of PPL Energy Supply (See Note 8) (207) (55) 238 (24) December 31, 2015 $ (520) $ $ (7) $ $ (6) $ (2,195) $ (2,728) LKE December 31, 2012 $ 1 $ (2) $ (14) $ (15) Amounts arising during the year 28 28 Net OCI during the year 28 28 December 31, 2013 $ 1 $ (2) $ 14 $ 13 Amounts arising during the year (7) (50) (57) Reclassifications from AOCI (1) 1 (1) (1) Net OCI during the year (1) (6) (51) (58) December 31, 2014 $ $ (8) $ (37) $ (45) Amounts arising during the year (3) (4) (7) Reclassifications from AOCI 1 5 6 Net OCI during the year (2) 1 (1) December 31, 2015 $ $ (10) $ (36) $ (46) The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2015 and 2014 . The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization . See Note 11 for additional information. PPL Affected Line Item on the Details about AOCI 2015 2014 Statements of Income Available-for-sale securities $ 4 $ 13 Other Income (Expense) - net Total Pre-tax 4 13 Income Taxes (2) (7) Total After-tax 2 6 Qualifying derivatives Interest rate swaps (11) (16) Interest Expense (77) Discontinued operations Cross-currency swaps 49 57 Other Income (Expense) - net 2 4 Interest Expense Commodity contracts 20 42 Discontinued operations Total Pre-tax (17) 87 Income Taxes 15 (23) Total After-tax (2) 64 Equity Investees' AOCI 1 Other Income (Expense) - net Total Pre-tax 1 Income Taxes Total After-tax 1 Defined benefit plans Prior service costs (7) Net actuarial loss (192) (145) Total Pre-tax (192) (152) Income Taxes 46 37 Total After-tax (146) (115) Total reclassifications during the year $ (145) $ (45)

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2015
New Accounting Guidance Pending Adoption [Abstract]
New Accounting Guidance Pending Adoption	21 . 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 per iods after December 15, 2017 and interim periods within those years. Public business entities may early adopt this guidance in annual reporting periods beginning after December 15, 2016. The Registrants expect to adopt this guidance effective January 1, 2018. The Registrants are currently assessing the impact of adopting this guidance, as well as the transition method they will use.

SCHEDULE I - CONDENSED UNCONSOL

SCHEDULE I - CONDENSED UNCONSOLICATED FINANCIAL STATEMENTS AND NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS	12 Months Ended
	Dec. 31, 2015
PPL Corp [Member]
Condensed Unconsolidated Financial Information [Line Items]
Schedule I - Condensed Unconsolidated Financial Information	SCHEDULE I - PPL CORPORATION CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME FOR THE YEARS ENDED DECEMBER 31, (Millions of Dollars, except share data) 2015 2014 2013 Operating Revenues Operating Expenses Other operation and maintenance $ 9 $ 16 $ 1 Total Operating Expenses 9 16 1 Operating Loss (9) (16) (1) Other Income (Expense) - net Equity in earnings of subsidiaries 711 1,776 1,171 Other income (expense) (15) (18) (13) Total 696 1,758 1,158 Interest Expense 9 15 21 Interest Expense with Affiliates 10 10 29 Income Before Income Taxes 668 1,717 1,107 Income Taxes (14) (20) (23) Net Income $ 682 $ 1,737 $ 1,130 Comprehensive Income Attributable to PPL Shareowners $ 252 $ 1,028 $ 1,505 Earnings Per Share of Common Stock: Net Income Available to PPL Common Shareowners: Basic $ 1.01 $ 2.64 $ 1.85 Diluted $ 1.01 $ 2.61 $ 1.76 Weighted-Average Shares of Common Stock Outstanding (in thousands) Basic 669,814 653,504 608,983 Diluted 672,586 665,973 663,073 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - PPL CORPORATION CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, (Millions of Dollars) 2015 2014 2013 Cash Flows from Operating Activities Net cash provided by (used in) operating activities $ 993 $ 1,633 $ 968 Cash Flows from Investing Activities Capital contributions to affiliated subsidiaries (491) (1,045) (496) Return of capital from affiliated subsidiaries 112 247 213 Net cash provided by (used in) investing activities (379) (798) (283) Cash Flows from Financing Activities Issuance of equity, net of issuance costs 203 1,074 1,411 Net increase (decrease) in short-term debt with affiliates 215 (913) (1,057) Payment of common stock dividends (1,004) (967) (878) Contract adjustment payments on Equity Units (22) (82) Repurchase of common stock (74) Other (28) (7) (5) Net cash provided by (used in) financing activities (614) (835) (685) Net Increase (Decrease) in Cash and Cash Equivalents Cash and Cash Equivalents at Beginning of Period Cash and Cash Equivalents at End of Period $ $ $ Supplemental Disclosures of Cash Flow Information: Cash Dividends Received from Affiliated Subsidiaries $ 1,198 $ 1,388 $ 960 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - PPL CORPORATION CONDENSED UNCONSOLIDATED BALANCE SHEETS AT DECEMBER 31, (Millions of Dollars, shares in thousands) 2015 2014 Assets Current Assets Accounts Receivable Other $ 10 $ 53 Affiliates 20 149 Price risk management assets 139 148 Total Current Assets 169 350 Investments Affiliated companies at equity 10,479 15,426 Other Noncurrent Assets Deferred income taxes 100 34 Price risk management assets 133 75 Other noncurrent assets 1 13 Total Other Noncurrent Assets 234 122 Total Assets $ 10,882 $ 15,898 Liabilities and Equity Current Liabilities Short-term debt with affiliates $ 385 $ 170 Accounts payable with affiliates 16 1,513 Dividends 255 249 Price risk management liabilities 268 227 Other current liabilities 65 Total Current Liabilities 924 2,224 Deferred Credits and Other Noncurrent Liabilities 39 46 Equity Common stock - $0.01 par value (a) 7 7 Additional paid-in capital 9,687 9,433 Earnings reinvested 2,953 6,462 Accumulated other comprehensive loss (2,728) (2,274) Total Equity 9,919 13,628 Total Liabilities and Equity $ 10,882 $ 15,898 (a) 780,000 shares authorized; 673,857 and 665,849 shares issued and outstanding at December 31, 2015 and 2014 . The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - PPL CORPORATION NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS 1. Basis of Presentation PPL Corporation is a holding company and conducts substantially all of its business operations through its subsidiaries. Substantially all of its consolidated assets are held by such subsidiaries. Accordingly, its cash flow and its ability to meet its obligations are largely dependent upon the earnings of these subsidiaries and the distribution or other payment of such earnings to it in the for m of dividends, loans or advances or repayment of loans and advances from it. These condensed financial statements and related footnotes have been prepared in accordance with Reg. §210.12-04 of Regulation S-X. These statements should be read in conjuncti on with the consolidated financial statements and notes thereto of PPL Corporation . PPL Corporation indirectly or directly owns all of the ownership interests of its significant subsidiaries. PPL Corporation relies on dividends or loans from its subsidia ries to fund PPL Corporation 's dividends to its common share owners and to meet its other cash requirements. See Note 7 to PPL Corporation’s consolidated financial statements for discussions related to restricted net assets of its subsidiaries for the p urposes of transferring funds to PPL in the form of distributions, loans or advances. Balance Sheet Classification of Deferred Taxes Effective October 1, 2015, PPL Corporation retrospectively adopted accounting guidance to simplify the presentation of deferred taxes which requires that deferred tax assets and deferred tax liabilities be classified as noncurrent on the balance sheet. T he adoption of this guidance required PPL Corporation to reclassify deferred tax assets and deferred tax liabilities from current to noncurrent on the balance sheet, and did not have a significant impact. PPL Corporation reclassified $34 million from curr ent deferred tax assets to noncurrent deferred tax assets and $5 million from current deferred tax liabilities to noncurrent deferred tax liabilities on the balance sheet as of December 31, 2014. 2. Commitments and Contingencies See Note 13 to PPL Corporation ’s consolidated financial statements for commitments and contingencies of its subsidiaries. Guarantees and Other Assurances PPL Corporation's subsidiaries are separate and distinct legal entities and have no obligation to pay any amounts that may become due under PPL Corporation's guarantees or other assurances or to make any funds available for such payment. PPL Corporation fully and unconditionally guarantees the payment of principal, premium and interest on all of the debt securities of PPL Capital Funding. The estimated maximum potential amount of future payments that could be required under the guarantees at December 31, 2015 was $8.4 billion. These guarantees will expire in 2073. The probability of expected payment under these guara ntees is remote.
L G And E And K U Energy L L C Unconsolidated [Member]
Condensed Unconsolidated Financial Information [Line Items]
Schedule I - Condensed Unconsolidated Financial Information	SCHEDULE I - LG&E and KU Energy LLC CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME FOR THE YEARS ENDED DECEMBER 31, (Millions of Dollars) 2015 2014 2013 Equity in Earnings of Subsidiaries $ 390 $ 368 $ 376 Interest Income with Affiliate 4 5 5 Interest Expense 39 41 39 Interest Expense with Affiliate 5 3 3 Income Before Income Taxes 350 329 339 Income Tax Expense (Benefit) (14) (15) (8) Net Income Attributable to Member $ 364 $ 344 $ 347 Comprehensive Income Attributable to Member $ 363 $ 286 $ 375 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - LG&E and KU Energy LLC CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, (Millions of Dollars) 2015 2014 2013 Cash Flows from Operating Activities Net cash provided by (used in) operating activities $ 246 $ (183) $ 136 Cash Flows from Investing Activities Capital contributions to affiliated subsidiaries (140) (248) (243) Net decrease (increase) in notes receivable from affiliates 73 555 (122) Net cash provided by (used in) investing activities (67) 307 (365) Cash Flows from Financing Activities Net increase (decrease) in notes payable with affiliates 315 58 171 Net increase (decrease) in short-term debt 75 Retirement of long-term debt (400) Contribution from member 125 248 243 Distribution to member (219) (436) (254) Net cash provided by (used in) financing activities (179) (130) 235 Net Increase (Decrease) in Cash and Cash Equivalents (6) 6 Cash and Cash Equivalents at Beginning of Period 6 Cash and Cash Equivalents at End of Period $ $ $ 6 Supplemental disclosures of cash flow information: Cash Dividends Received from Affiliated Subsidiaries $ 272 $ 260 $ 223 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - LG&E and KU Energy LLC CONDENSED UNCONSOLIDATED BALANCE SHEETS AT DECEMBER 31, (Millions of Dollars) 2015 2014 Assets Current Assets Accounts receivable $ 1 $ 8 Accounts receivable from affiliates 3 Notes receivable from affiliates 1,054 1,127 Total Current Assets 1,058 1,135 Investments Affiliated companies at equity 5,076 4,818 Other Noncurrent Assets Deferred income taxes 228 205 Other noncurrent assets 1 Total Other Noncurrent Assets 228 206 Total Assets $ 6,362 $ 6,159 Liabilities and Equity Current Liabilities Short-term debt $ 75 $ 75 Notes payable to affiliates 69 58 Long-term debt due within one year 400 Accounts payable to affiliates 469 451 Taxes 3 2 Other current liabilities 5 8 Total Current Liabilities 621 994 Long-term Debt Long-term debt 720 718 Notes payable to affiliates 500 196 Total Long-term Debt 1,220 914 Deferred Credits and Other Noncurrent Liabilities 4 3 Equity 4,517 4,248 Total Liabilities and Equity $ 6,362 $ 6,159 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. Schedule I – LG&E and KU Energy LLC Notes to Condensed Unconsolidated Financial Statements 1. Basis of Presentation LG&E and KU Energy LLC (LKE) is a holding company and conducts substantially all of its business operations through its subsidiaries. Substantially all of its consolidated assets are held by such subsidiaries. Accordingly, its cash flow and its ability to meet its obligations are largely dependent upon the earnings of these subsidiaries and the distribution or other payment of such earn ings to it in the form of dividends or repayment of loans and advances from the subsidiaries . These condensed financial statements and related footnotes have been prepared in accordance with Reg. §210.12-04 of Regulation S-X. These statements should be r ead in conjunction with the consolidated financial statements and notes thereto of LKE. LKE indirectly or directly owns all of the ownership interests of its significant subsidiaries. LKE relies primarily on dividends from its subsidiaries to fund LKE's dividends to its member and to meet its other cash requirements. See Note 7 to LKE’s consolidated financial statements for discussions related to restricted net assets of its subsidiaries for the purposes of transferring funds to LKE in the form of dis tributions, loans or advances. Balance Sheet Classification of Deferred Taxes Effective October 1, 2015, LKE retrospectively adopted accounting guidance to simplify the presentation of deferred taxes which requires that deferred tax assets and deferred tax liabilities be classified as noncurrent on the balance sheet. The adoption of this guidance required LKE t o reclassify deferred tax assets and deferred tax liabilities from current to noncurrent on the balance sheet, and did not have a significant impact. LKE reclassified $ 2 million from current deferred tax assets to noncurrent deferred tax assets on the bal ance sheet as of December 31, 2014. Presentation of Debt Issuance Costs Effective December 31, 2015, LKE retrospectively adopted accounting guidance to simplify the presentation of debt issuance costs. The guidance requires certain debt issuance costs to be prese nted on the balance sheet as a direct deduction from the carrying amount of the associated debt liability. The adoption of this guidance required LKE to reclassify debt issuance costs not associated with a line of credit from noncurrent assets to Long-term debt, and did not have a significant impact on the Registrants. LKE reclassified $4 million from Other noncurrent assets to Long-term debt on the balance sheet as of December 31, 2014. 2. Commitments and Contingencies See Note 13 to LKE’s consolidated financial statements for commitments and contingencies of its subsidiaries. Guarantees LKE provides certain indemnifications, the most significant of which relate to the termination of the WKE lease in July 2009. These guarantees cover the due and punctual payment, performance and discharge by each party of its respective present and future obligations. The most comprehensive of these WKE-related guarantees is the LKE guarantee covering operational, regulatory and environmental co mmitments and indemnifications made by WKE under the WKE Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a cumulative maximum exposure of $200 million. Certain items such as government fines and penalties fa ll outside the cumulative cap. Another WKE-related LKE guarantee covers other indemnifications, 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 interpr eting 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, a cou nterparty issued a demand letter to LKE's indemnitee . LKE does not believe appropriate contractual, legal or commercial grounds exist for the claim made and anticipates the indemnitee to dispute the demand. 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. The ultimate outcomes of the WKE termination-related indemnif ications can not 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 indemni fication circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded. 3. Long-term Debt See Note 7 to LKE’s consolidated financial statements for the terms of LKE’s outstanding s enior u nsecured n otes outstanding . Of the total outstanding, $475 million matures in 2020 and $250 million matures in 2021. These maturities are based on stated maturities .

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Unaudited [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL, COMMON STOCK PRICE AND DIVIDEND DATA (Unaudited) PPL Corporation and Subsidiaries (Millions of Dollars, except per share data) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2015 Operating revenues $ 2,230 $ 1,781 $ 1,878 $ 1,780 Operating income 890 638 686 617 Income from continuing operations after income taxes 552 250 396 405 Income (loss) from discontinued operations (net of income taxes) (d)(e) 95 (1,007) (3) (6) Net income (loss) (e) 647 (757) 393 399 Income from continuing operations after income taxes available to PPL common shareowners: (b) Basic EPS 0.83 0.37 0.59 0.60 Diluted EPS 0.82 0.37 0.59 0.60 Net income (loss) available to PPL common shareowners: (b) Basic EPS 0.97 (1.13) 0.58 0.59 Diluted EPS 0.96 (1.13) 0.58 0.59 Dividends declared per share of common stock (c) 0.3725 0.3725 0.3775 0.3775 Price per common share: High $ 36.38 $ 34.85 $ 33.58 $ 34.75 Low 31.40 29.45 29.41 32.60 2014 Operating revenues $ 2,178 $ 1,849 $ 1,879 $ 1,946 Operating income 801 678 688 700 Income from continuing operations after income taxes 389 230 410 408 Income (loss) from discontinued operations (net of income taxes) (d)(f) (73) (1) 87 287 Net income (f) 316 229 497 695 Income from continuing operations after income taxes available to PPL common shareowners: (b) Basic EPS 0.61 0.35 0.61 0.62 Diluted EPS 0.61 0.34 0.61 0.62 Net income available to PPL common shareowners: (b) Basic EPS 0.50 0.35 0.74 1.04 Diluted EPS 0.49 0.34 0.74 1.04 Dividends declared per share of common stock (c) 0.3725 0.3725 0.3725 0.3725 Price per common share: High $ 33.24 $ 35.56 $ 35.52 $ 38.14 Low 29.40 32.32 31.79 32.09 (a) Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations. ( b ) The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding. (c ) PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future d ividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors. (d ) In the second quarter of 2015, PPL completed the spinoff of PPL Energy Supply sub stantially representing PPL's Supply segment. Accordingly, the previously reported operating results for PPL’s Supply segment have been reclassified as discontinued operations. See Note 8 to the Financial Statements for additional information. (e) The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information. (f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Unaudited [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL DATA (Unaudited) PPL Electric Utilities Corporation and Subsidiaries (Millions of Dollars) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2015 Operating revenues $ 630 $ 476 $ 519 $ 499 Operating income 175 116 121 126 Net income 87 49 55 61 2014 Operating revenues $ 592 $ 449 $ 477 $ 526 Operating income 165 111 124 138 Net income 85 52 57 69 (a) PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

Summary of Significant Accoun33

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Summary Of Significant Accounting Policies [Line Items]
Business and Consolidation	Business and Consolidation (PPL) PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the distribution of electricity in the U.K.; 2) the g eneration, transmission , distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 3) the transmission , distribution and sale of electricity in Pennsylvania . Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global , LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. WPD, a subsidiary of PPL Global, through indirect wholly owned subsidiaries operates distribution networks providing electricit y service in the U.K. WPD serves end-users in South Wales and southwest and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands) and WPD (West Midlands). PPL consolidates WPD on a one-month lag. Mater ial events, such as debt issuances that occur in the lag period, are recognized in the current period financial statements. Events that are significant but not material are disclosed . (PPL and PPL Electric) PPL Electric is a cost-based rate-regulated u tility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail cus tomers in that territory as a PLR. (PPL , LKE, LG&E and KU ) LKE is a utility holding company with cost-based rate- regulated utility operations through its subsidiaries, LG&E and KU . LG&E and KU are engaged in the generation, transmission, distribution and sale of electric ity . LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia (under the Old Dominion Power name) and in Tennessee under the KU name. (PPL ) "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statements of Income includes the activities of PPL Energy Supply, substantially representing PPL's fo rmer Supply segment, which was spun off and distributed to PPL shareowners on June 1, 2015. PPL Energy Supply's assets and liabilities have been reclassified on PPL's Balance Sheet at December 31, 2014 to "Current assets of discontinued operations", "Nonc urrent assets of discontinued operations", "Current liabilities of discontinued operations" and "Noncurrent liabilities of discontinued operations". These assets and liabilities were distributed and removed from PPL's Balance Sheet in the second quarter o f 2015. In addition, the Statements of Cash Flows separately report the cash flows of the discontinued operations. See Note 8 for additional information. ( All Registrants ) The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Var iable Interest Entities ( VIEs ) . The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE, and thus are the primary beneficiary of the entity. T he Registrants are not the primary beneficiary in any VIEs. Inv est ments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. All significant intercompany transactions have been eliminated. The financial statements of PPL, LKE, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 12 for additional information.
Regulation	Regulation (PPL) WPD operates in an incentive-based regulatory structure under distribution licenses granted by Ofgem . Electricity distribution revenues are set by Ofgem for a given time period through price control reviews that are not directly based on cost recovery. The price control formula that governs WPD's allowed revenue is designed to provide economic incentives to minimize operating, capital and financing costs . As a result, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. (All Registrants) PPL Electric, LG&E and KU are cost-based rate-regulated utiliti es for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a futu re test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or ev ents where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incu rred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decis ions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
Accounting Records	Accounting Records (All Registrants) The system of accounts for domestic regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Loss Accruals	Loss Accruals Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of the uncertain future events and (2) the amount of the loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other e vents. L oss accruals for environmental remediation are discounted when appropriate. T he accrual of contingencies that might result in gains is not recorded , unless re alization is assured.
Changes in Classification	Changes in Classification The classification of certain amounts in the 2014 and 2013 financial statements have been changed to conform to the current presentation. These reclassifications did not affect the Registrants' net income or equity.
Earnings Per Share	Earnings Per Share ( PPL ) EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-based payment awards that provide recipients a non-forfeitable right to dividends or dividend equivalents are considered participating securities.
Price Risk Management	Price Risk Management ( All Registrants ) I nterest rate contracts are used to hedge exposure to change in the fair value of debt instruments and to hedge exposure s to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. F oreign currency exchange contracts are used to hedge foreign currency exposures , primarily associated with PPL's investments in U.K. subsidiaries . Similar derivatives may receive different acc ounting treatment, depending on management’s intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved that would facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. The portion of derivative positions that deliver within a year are included in "Current Assets" and "Current Liabilities," while the portion of derivative positions that deliver beyond a year are recorded in "Other Noncurrent Assets" and "Deferred Credits and Other Noncurrent Liabilities." See Note 17 to the Financi al Statements for additional information. (PPL) Processes exist that allow for subsequent review and validation of the contract information as it relates to interest rate and foreign currency derivatives. See Note 17 for more information. The acc ounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limit ed to :  Transactions to lock in an interest rate prior to a debt issuance can be d esignated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring.  Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges.  Transactions entered into to hedge fluctuations in the fair value of existing debt can be d esignated as fair value hedges.  Transactions entered into to hedge the value of a net investment of foreign operations can be designated as net investment hedges.  Derivative transactions that do not qualify for cash flow or net investment hedge t reatment are marked to fair value through earnings. These transactions generally include foreign currency forwar ds and options to hedge GBP earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP . As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates.  Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are includ ed in customer rates. (All Registrants) Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. ( PPL and PPL Electric ) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative . However, NPNS has been elected for the se contracts. See Notes 16 and 17 for additional information on derivatives .
Revenue Recognition	Revenue Recognition (All Registrants ) Operating revenues are primarily recorded based on energy deliveries through the end of the calendar month. Unbilled retail revenues result because customers' meters are read and bills are rendered throughout the month, rather than all meters being read and bills rendered at the end of the month. For LKE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh by the estimated average cents per kWh . For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled kWh by the estimated average cents per kWh. An y difference between estimated and actual revenues is adjusted the following month. (PPL) WPD is currently operating under RIIO - ED1, which commenced on April 1, 2015. Ofgem has adopted a price control mechanism that establishes the amount of base dema nd revenue WPD can earn during the price control period, subject to certain true-ups, and provides for an increase or reduction in revenues based on incentives or penalties for exceeding or underperforming relative to pre-established targets. WPD’s allowe d revenue primarily includes base demand revenue, incentive adjustments, adjustments for over or under-recovery and adjustments related to the DPCR4 line loss close out. As the regulatory model is incentive based rather than a cost recovery model, WPD i s not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. Therefore, the accounting treatment of adjustments to base demand revenue and/or allowed revenue is evaluated based on revenue recognition and contingency gu idance. Unlike prior price control reviews, base demand revenue under RIIO – ED1 will be adjusted during the price control period. The most significant of those adjustments are: Inflation True-Up – The base demand revenue for the RIIO-ED1 period was s et in 2012/13 prices. Therefore an inflation factor as determined by forecasted RPI, provided by HM Treasury, is applied to base demand revenue. Forecasted RPI is trued up to actuals and affects future base demand revenue two regulatory years later. Thi s revenue change is called the "TRU" adjustment. The projected TRU for the 2015/16 regulatory year is a $45 million reduction to revenue and will reduce base demand revenue in calendar years 2017 and 2018 by $30 million and $15 million, respectively. Annual Iteration Process - The RIIO-ED1 price control period also includes an Annual Iteration Process (AIP). This will allow future base demand revenues agreed with the regulator as part of the price control review to be updated during the price control period for financial adjustments including tax, pensions and cost of debt, legacy price control adjustments from preceding price control periods and adjustments relating to actual and allowed total expenditure together with the Totex Incentive Mechanism (T IM). Under the TIM, WPD's DNOs are able to retain 70% of any amounts not spent against the RIIO-ED1 plan and bear 70% of any over-spends. The AIP calculates an incremental change to base demand revenue, known as the "MOD" adjustment. The MOD provided by Ofgem in November 2016 will include the TIM for the 2015/16 regulatory year as well as the cost of debt calculation based on the 10-year trailing average to October 2016. This projected MOD of $11 million will reduce base demand revenue for calendar years 2017 and 2018 by $5 million and $6 million, respectively. As both MOD and TRU are changes to future base demand revenues as determined by Ofgem , under applicable GAAP, liabilities for these adjustments have not been recorded. In addition to base deman d revenue, certain other items are added or subtracted to arrive at allowed revenue. The most significant of these are: Incentives - Ofgem has established incentive mechanisms to provide significant opportunities to enhance overall returns by improving network efficiency, reliability and customer service. Based on applicable GAAP, incentive revenues are not recorded as assets and are includ ed in revenues when they are billed to customers. DPCR4 Line Loss Adjustment - For regulatory years 2015/16 through 2018/19 allowed revenue will also be reduced to reflect Ofgem's final decision on the DPCR4 line loss incentives and penalties mechanism. WPD has a liability recorded related to this future revenue reduction and, therefore, this will not impact future earnings. See Note 6 to the Financial Statements for additional information. Correction Factor - During the price control period, WPD's revenue is decoupled from volume and WPD sets its tariffs to recover allowed revenue. However, in any fiscal period, WPD's revenue could be negatively affected if its tariffs and the volume delivered do not fully recover the allowed revenue for a particul ar period. Conversely, WPD could also over-recover revenue. Over and under-recoveries are subtracted from or added to allowed revenue in future years, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising from 2014/15 onwards and refunded/recovered under RIIO-ED1 will be refunded/recovered on a two year lag (previously one year). Therefore the 2014/15 over/under-recovery adjustment will occur in 2016/17. In 2016/17 under this mechanism, WPD will recover the £5 per res idential network customer reduction given through reduced tariffs in 2014/15 (approximately $56 million) as that amount is currently considered an under-recovery. Under applicable GAAP, WPD does not record a receivable for under-recoveries, but does reco rd a liability for over-recoveries. K-factor is measured as of the end of the regulatory year, March 31. While WPD estimates over-recoveries and records a liability when it is probable that there will be an over-recovered position at the end of the regul atory-year, weather-related volume changes and other factors such as sales mix can affect the over or under-recovery between the end of PPL's calendar year and the end of the regulatory year.
Accounts Receivable	Accounts Receivable (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. (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. The purchased accounts receivable are initially recorded at fair value using a market approach based on th e purchase price paid and are classified as Level 2 in the f air value hierarchy. During 2015 , 2014 and 2013 , PPL Electric purchased $ 1.3 b illion , $ 1.1 b illion and $ 985 million of accounts receivable from unaffiliated third parties. During 2015 , 2014 and 2013 , PPL Electric purchased $ 146 million , $ 336 million and $ 294 million of accounts receivable from PPL EnergyPlus . PPL Electric's purchases from PPL EnergyPlus for 2015 include purchases through May 31, 2015, which is the period during which PPL Electric and PPL EnergyPlus were affiliated ent ities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL Electric's purchases from Talen Energy Marketing subsequent t o May 31, 2015 are included as purchases from an unaffiliated third party. Allowance for Doubtful Accounts (All Registrants) Accounts receivable collectability is evaluated using a combination of factors, including past due status based on contractual terms, trends in write-offs, the age of the receivable, counterparty creditworthiness and economic conditions. Specific events, such as bankruptcies, are also considered. Adjustments to the allowance for doubtful accounts are made when necessary based on the results of analysis, the aging of receivables and historical and industry trends. Accounts receivable are written off in th e period in which the receivable is deemed uncollectible. Recoveries of accounts receivable previously written off are recorded when it is known they will be received.
Cash	Cash Cash Equivalents (All Registrants) All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. Restricted Cash and Cash Equivalents (PPL and PPL Electric) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. The change in restricted cash and cash equivalents is reported as an investing activity on the Statements of Cash Flows. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets" , while the noncurrent portion is included in "Other noncurrent ass ets. "
Fair Value Measurements	Fair Value Measurements ( All Registrants ) The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securitie s in defined benef it plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows:  Level 1 - q uoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pr icing information on an ongoing basis.  Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability.  Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value. Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liabili ty. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy.
Investments	Investments ( All Registrants ) Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term. Short-term Investments Short-term investments generally inc lude certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturi ties of greater than a year that management has the ability a nd intent to sell within a year, are included in “Short-term investments” (“Other current assets” if not significant ) on the Balance Sheets. Cost Method Investment ( PPL, LKE, LG&E and KU) LG&E and KU each have an investment in OVEC, which is accounted for using the cost method. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E’s and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of t heir investments; however, LG&E and KU are conditionally responsible for a pro-rata share of certain OVEC obligations. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting reg ulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 13 and 18 for additional discussion of the power purchase agreement.
Property, Plant and Equipment	Property, Plant and Equipment ( All Registrants ) PP&E is recorded at original cost, unless impaired. PP&E acquired in business combinations is recorded at fair value at the time of acquisition, which establishes its original cost. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which the cost s are incurred. No costs associated with planned major maintenance projects are accrued in advance of the period in which the work is performed. LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. See "Asset Retirement Obligations" below and Note 6 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices. AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC, except for certain instanc es in KU’s FERC approved rates charged to its municipal customers, as a return is provided on construction work in progress . (PPL) PPL capitalizes interest costs as part of construction cost s. Depreciation (All Registrants) Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired , the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators.
Goodwill and Other Intangible Assets	(All Registrants) Goodwill and Other Intangible Assets Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination. Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets. When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider the expected use of the asset; the expected useful life of other assets to which the useful life of the intangible asset may relate; legal, regulatory, or contractual provisions that may limit the useful life; the company' s historical experience as evidence of its ability to support renewal or extension; the effects of obsolescence, demand, competition, and other economic factors; and the level of maintenance expenditures required to obtain the expected future cash flows fr om the asset. PPL, LKE, LG&E and KU account for emission al lowances as intangible assets. LG&E and KU are allocated emission allowances by states based on their generation facilities ' historical emissions experience, and have purchased emission allowances generally when it is expected that additional allowances will be needed. The carrying value of allocated emission allowances is initially recorded at zero value and purchased allowances are initially recorded based on their purchase price. Wh en consumed or sold, emission allowances are removed from the Balance Sheet at their weighted-average carrying value. Since the economic benefits of emission allowances are not diminished until they are consumed, emission allowances are not amortized; rat her, they are expensed when consumed or a gain or loss is recognized when sold. Such expense is included in " Fuel " on the Statements of Income. Gains and losses on the sale of emission allowances are included in " Other operation and maintenance " on the S tatements of Income.
Asset Retirement Obligations	Asset Retirement Obligations ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, whic h is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in t he obligation due to the passage of time . The accretion and depreciation expenses recorded by LG&E and KU are recorded as a regulatory asset, such that there is no earnings impact . Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the r emaining life of the associated long-lived asset. See Note 19 for additional information on AROs.
Compensation and Benefits	Compensation and Benefits Defined Benefits (All Registrants) Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. The expected return on plan assets is determ ined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value. PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the expected average remaining service of active plan participants. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the p lan's projected benefit obligation are amortized on a straight-line basis over the expected average remaining service period of active plan participants. See Note 6 for a discussion of the regulatory treatment of defined benefit costs and Note 11 for a discussion of defined benefits. Stock-Based Compensation ( PPL, PPL Electric and LKE) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certa in employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value meth od. Stock options that vest in installments are valued as a single award. PPL grants stock options with an exercise price that is not less than the fair value of PPL 's common stock on the date of grant. See Note 10 for a discussion of stock-based com pensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric and LKE includes an allocation of PPL Services' expense.
Income Taxes	Taxes Income Taxes ( All Registrants ) PPL and its domestic subsidiaries file a consolidated U.S. federal income tax return. Significant management judgment is required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken in tax returns, valuation allowances on deferred tax assets and whether the undistributed earnings of WPD are considered indefinitely reinvested. Significant management judgment is also required to determine the amount of benefit to be recognized in relation to an uncertain tax position. The Registrants use a two-step process to evaluate tax positions. The first step requires an entity to determine whether, based on the technical merit s supporting a particular tax position, it is more likely than not (greater than a 50% chance) that the tax position will be sustained. This determination assumes that the relevant taxing authority will examine the tax position and is aware of all the relevant facts surrounding the tax position. The second step requires an entity to recognize in the financial statements the benefit of a tax position that meets the more-likely-than-not recognition criterion. The benefit recogni zed is measured at the largest amount of benefit that has a likelihood of realization, upon settlement, that exceeds 50% . The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements of the Registrants in future periods. Deferred income taxes reflect the net future tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes, as well as the tax effects of net operating losses and tax credit carryforwards . The Registrants record valuation allowances to reduce deferred tax assets to the amounts that are more likely th an not to be realized. The Registrants consider the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies in initially recording and subsequently reevaluating the need for valuation allowances. If the Registrants determine that they are able to realize deferred tax assets in the future in excess of recorded net deferred tax assets, adjustments to the valuation allowances increase income by reducing tax expense in the period that such determinatio n is made. Likewise, if the Registrants determine that they are not able to realize all or part of net deferred tax assets in the future, adjustments to the valuation allowances would decrease income by increasing tax expense in the period that such deter mination is made. The Registrants defer investment tax credits when the credits are utilized and amortize the deferred amounts over the average lives of the related assets. The Registrants recognize interest and penalties in "Income Taxes" on the ir Statements of Income. See Note 5 for additional discussion regarding income taxes including management’s conclusion that the undistributed earnings of WPD are considered indefinitely reinvested. Based on this conclusion, PPL Global does not reco rd U.S. taxes on WPD’s undistributed earnings. The provision for PPL, PPL Electric, LKE, LG& E and KU's deferred income taxes for regulated assets is based upon the ratemaking principles reflected in rates established by the regulators. The difference in the provision for deferred income taxes for regulated assets and the amount that otherwise wo uld be recorded under GAAP is deferred and included on the Balance Sheet in noncurrent "Regulatory assets" or "Regulatory liabilities."
Taxes, Other Than Income	Taxes, Other Than Income ( All Registrants ) The Registrants present sales taxes in " Other current liabilities " and PPL presents value -added taxes in "Taxes" on the Balance Sheets. These taxes are not reflected on the Statements of Income. See Note 5 for details on taxes included in "Taxes, other than income" on the Statements of Income.
Leases	( All Registrants ) Leases The Registrants evaluate whether arrangements entered into contain leases for accounting purposes. See Note 9 for additional information.
Fuel, Materials and Supplies	Fuel, Materials and Supplies Fuel, natural gas stored underground and materials and supplies are valued at the lower of cost or net realizable value using the average cost method. Fuel costs for electric generation are charged to expense as used. For LG&E, natural gas supply costs are charged to expense as delivered to the distribution system. See Note 6 for further discussion of the fuel adjustment clause and gas supply clause.
Guarantees	Guarantees ( All Registrants ) Generally, the initial measurement of a guarantee liability is the fair value of the guarantee at its inception. However, there are certain guarantees excluded from the scope of accounting guidance and other guarantees that are not subject to the initial recognition and measurement provisions of accounting guidance that only require d i sclosure . See Note 13 for further discussion of recorded and unrecorded guarantees.
Treasury Stock	Treasury Stock ( PPL and PPL Electric) PPL and PPL Electric restore all shares of common stock acquired to authorized but unissued shares o f common stock upon acquisition.
Asset Impairment (Excluding Investments)	Asset Impairment (Excluding Investments) The Registrants review long-lived assets that are subject to depreciation or amortization, including finite-lived intangibles, for impairment when events or circumstances indicate carrying amounts may not be recoverable. A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's c arrying value is written down to its fair value. A long-lived asset classified as held for sale is impaired when the carrying amount of the asset (disposal group) exceeds its fair value less cost to sell. If impaired, the asset's (disposal group's) carrying value is written down to its fair value less cost to sell. PPL, LKE, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or cir cumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, LKE's, LG&E's and KU's reporting units are at the operating segment level. PPL, LKE, LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the q ualitative evaluation and test goodwill for impairment using a two-step quantitative test. If the qualitative evaluation (referred to as "step zero") is elected and the assessment results in a determination that it is not more likely than not that the fai r value of a reporting unit is less than the carrying amount, the two-step quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a rep orting unit is less than the carrying amount based on the step zero assessment. If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, the implied fair value of goodwill must be calculated in the same manner as goodwill in a business combination. The fair value of a reporting unit is allocated to all assets and liabilities of that unit as if the reporting unit had been acquired in a business combination. The excess of the fair value of the reporting unit over the amount s assigned to its assets and liabilities is the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, goodwill is written down to its implied fair value. PPL (for its U.K. Regulated and Kentucky Regulated segments), and individually, LKE, LG&E and KU elected to bypass step zero and quantitatively tested the goodwill of these reporting units for impairment in the fourth quarter of 2015 and no impairme nt was reco gnized.
Foreign Currency Translation and Transactions	Foreign Currency Translation and Transactions ( PPL ) WPD's functional currency is the GBP, which is the local currency in the U.K. As such, assets and liabilities are translated to U.S. dollars at the exchange rates on the date of consolidation and related revenues and expenses are generally translated at average exchange rates prevailing during the period included in PPL's results of operations . Adjustments resulting fr om foreign currency translation ar e recorded in A OCI. Gains or losses relating to foreign currency transactions are recognized in "Other Income (Expense) - net" on the Statements of Income. See Note 15 for additional information.
New Accounting Guidance Adopted	New Accounting Guidance Adopted ( All Registrants ) Reporting of Discontinued Operations Effective January 1, 2015, the Registrants prospectively adopted accounting guidance that changes the criteria for determining what should be classified as a discontinued operation and the related presentation and disclosure requirements. A discontinued operation may include a component of an entity or a group of components of an entity, or a business activity. A disposal of a component of an entity or a grou p of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has (or will have) a major effect on the entity's operations and financial results when any of the following occurs: (1) Th e components of an entity or group of components of an entity meets the criteria to be classified as held for sale, (2) The component of an entity or group of components of an entity is disposed of by sale, or (3) The component of an entity or group of com ponents of an entity is disposed of other than by sale (for example, by abandonment or in a distribution to owners in a spinoff). As a result of the spinoff on June 1, 2015, PPL Energy Supply has been reported as a discontinued operation under the new dis continued operations guidance. See Note 8 for additional information. Fair Value Measurement for Investments in Certain Entities that Calculate Net Asset Value per Share Effective December 31, 2015, the Registrants retrospectively adopted accountin g guidance that removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using net asset value per share and the requirement to make certain disclosures for all investments that are eligible to be measured using net asset value per share. The adoption of this guidance resulted in the Registrants no longer categorizing investments for which fair value is measured using net asset value per share in the fair value hierarchy, and did not have a sig nificant impact on the Registrants. See Note 11 for additional information. Presentation of Debt Issuance Costs Effective December 31, 2015, the Registrants retrospectively adopted accounting guidance to simplify the presentation of debt issuance cos ts. The guidance requires certain debt issuance costs to be presented on the balance sheet as a direct deduction from the carrying amount of the associated debt liability. The adoption of this guidance required the Registrants to reclassify debt issuance costs not associated with a line of credit from noncurrent assets to Long-term debt, and did not have a significant impact on the Registrants. See Note 7 for additional information. Balance Sheet Classification of Deferred Taxes Effective October 1, 2015, the Registrants retrospectively adopted accounting guidance to simplify the presentation of deferred taxes which requires that deferred tax assets and deferred tax liabilities be classified as noncurrent on the balance sheet. The adoption of this guidance required the Registrants to reclassify deferred tax assets and deferred tax liabilities from current to noncurrent on the balance sheet, and did not have a significant impact on the Registrants. The following table presents the amounts reclassifi ed from current deferred tax assets and liabilities to noncurrent deferred tax liabilities on the balance sheets as of December 31, 2014.
PPL Electric Utilities Corp [Member]
Summary Of Significant Accounting Policies [Line Items]
Business and Consolidation	PPL Electric is a cost-based rate-regulated u tility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail cus tomers in that territory as a PLR.
Price Risk Management	( PPL and PPL Electric ) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative . However, NPNS has been elected for the se contracts. See Notes 16 and 17 for additional information on derivatives .
Accounts Receivable	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. The purchased accounts receivable are initially recorded at fair value using a market approach based on th e purchase price paid and are classified as Level 2 in the f air value hierarchy. During 2015 , 2014 and 2013 , PPL Electric purchased $ 1.3 b illion , $ 1.1 b illion and $ 985 million of accounts receivable from unaffiliated third parties. During 2015 , 2014 and 2013 , PPL Electric purchased $ 146 million , $ 336 million and $ 294 million of accounts receivable from PPL EnergyPlus . PPL Electric's purchases from PPL EnergyPlus for 2015 include purchases through May 31, 2015, which is the period during which PPL Electric and PPL EnergyPlus were affiliated ent ities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL Electric's purchases from Talen Energy Marketing subsequent t o May 31, 2015 are included as purchases from an unaffiliated third party.
Cash	Restricted Cash and Cash Equivalents (PPL and PPL Electric) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. The change in restricted cash and cash equivalents is reported as an investing activity on the Statements of Cash Flows. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets" , while the noncurrent portion is included in "Other noncurrent ass ets. "
Compensation and Benefits	Stock-Based Compensation ( PPL, PPL Electric and LKE) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certa in employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value meth od. Stock options that vest in installments are valued as a single award. PPL grants stock options with an exercise price that is not less than the fair value of PPL 's common stock on the date of grant. See Note 10 for a discussion of stock-based com pensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric and LKE includes an allocation of PPL Services' expense.
Income Taxes	( PPL Electric, LKE, LG&E and KU ) The income tax provision for PPL Electric, LKE, LG& E and KU is calculated in accordance with an intercompany tax sharing agreement which provides that taxable income be calculated as if PPL Electric, LKE, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared betw een companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes. At December 31, the following intercompany tax receivables (payables) were recorded.
Treasury Stock	Treasury Stock ( PPL and PPL Electric) PPL and PPL Electric restore all shares of common stock acquired to authorized but unissued shares o f common stock upon acquisition.
LG And E And KU Energy LLC [Member]
Summary Of Significant Accounting Policies [Line Items]
Business and Consolidation	LKE is a utility holding company with cost-based rate- regulated utility operations through its subsidiaries, LG&E and KU . LG&E and KU are engaged in the generation, transmission, distribution and sale of electric ity . LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia (under the Old Dominion Power name) and in Tennessee under the KU name.
Investments	Cost Method Investment ( PPL, LKE, LG&E and KU) LG&E and KU each have an investment in OVEC, which is accounted for using the cost method. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E’s and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of t heir investments; however, LG&E and KU are conditionally responsible for a pro-rata share of certain OVEC obligations. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting reg ulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 13 and 18 for additional discussion of the power purchase agreement.
Asset Retirement Obligations	Asset Retirement Obligations ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, whic h is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in t he obligation due to the passage of time . The accretion and depreciation expenses recorded by LG&E and KU are recorded as a regulatory asset, such that there is no earnings impact . Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the r emaining life of the associated long-lived asset. See Note 19 for additional information on AROs.
Compensation and Benefits	Stock-Based Compensation ( PPL, PPL Electric and LKE) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certa in employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value meth od. Stock options that vest in installments are valued as a single award. PPL grants stock options with an exercise price that is not less than the fair value of PPL 's common stock on the date of grant. See Note 10 for a discussion of stock-based com pensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric and LKE includes an allocation of PPL Services' expense.
Income Taxes	( PPL Electric, LKE, LG&E and KU ) The income tax provision for PPL Electric, LKE, LG& E and KU is calculated in accordance with an intercompany tax sharing agreement which provides that taxable income be calculated as if PPL Electric, LKE, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared betw een companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes. At December 31, the following intercompany tax receivables (payables) were recorded.
Louisville Gas And Electric Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Business and Consolidation	LKE is a utility holding company with cost-based rate- regulated utility operations through its subsidiaries, LG&E and KU . LG&E and KU are engaged in the generation, transmission, distribution and sale of electric ity . LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia (under the Old Dominion Power name) and in Tennessee under the KU name.
Investments	Cost Method Investment ( PPL, LKE, LG&E and KU) LG&E and KU each have an investment in OVEC, which is accounted for using the cost method. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E’s and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of t heir investments; however, LG&E and KU are conditionally responsible for a pro-rata share of certain OVEC obligations. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting reg ulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 13 and 18 for additional discussion of the power purchase agreement.
Asset Retirement Obligations	Asset Retirement Obligations ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, whic h is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in t he obligation due to the passage of time . The accretion and depreciation expenses recorded by LG&E and KU are recorded as a regulatory asset, such that there is no earnings impact . Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the r emaining life of the associated long-lived asset. See Note 19 for additional information on AROs.
Income Taxes	( PPL Electric, LKE, LG&E and KU ) The income tax provision for PPL Electric, LKE, LG& E and KU is calculated in accordance with an intercompany tax sharing agreement which provides that taxable income be calculated as if PPL Electric, LKE, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared betw een companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes. At December 31, the following intercompany tax receivables (payables) were recorded.
Kentucky Utilities Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Business and Consolidation	LKE is a utility holding company with cost-based rate- regulated utility operations through its subsidiaries, LG&E and KU . LG&E and KU are engaged in the generation, transmission, distribution and sale of electric ity . LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia (under the Old Dominion Power name) and in Tennessee under the KU name.
Investments	Cost Method Investment ( PPL, LKE, LG&E and KU) LG&E and KU each have an investment in OVEC, which is accounted for using the cost method. The investment is recorded in "Other noncurrent assets" on the PPL, LKE, LG&E and KU Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU. LG&E’s and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of t heir investments; however, LG&E and KU are conditionally responsible for a pro-rata share of certain OVEC obligations. As part of PPL's acquisition of LKE, the value of the power purchase contract was recorded as an intangible asset with an offsetting reg ulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 13 and 18 for additional discussion of the power purchase agreement.
Asset Retirement Obligations	Asset Retirement Obligations ( PPL, LKE, LG&E and KU ) PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, whic h is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in t he obligation due to the passage of time . The accretion and depreciation expenses recorded by LG&E and KU are recorded as a regulatory asset, such that there is no earnings impact . Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the r emaining life of the associated long-lived asset. See Note 19 for additional information on AROs.
Income Taxes	( PPL Electric, LKE, LG&E and KU ) The income tax provision for PPL Electric, LKE, LG& E and KU is calculated in accordance with an intercompany tax sharing agreement which provides that taxable income be calculated as if PPL Electric, LKE, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared betw een companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes. At December 31, the following intercompany tax receivables (payables) were recorded.

Fair Value Measurements and C34

Fair Value Measurements and Credit Concentration (Policies)	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements and Credit Concentration [Abstract]
Fair Value Measurements	Transfers between levels are recognized at end-of-reporting-period values.

Derivative Instruments and He35

Derivative Instruments and Hedging Activities (Policies)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities [Abstract]
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim ca sh collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

Summary of Significant Accoun36

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Summary Of Significant Accounting Policies [Line Items]
Schedule of Utility Revenue	For the years ended December 31, the Statements of Income "Operating Revenues " line item contains revenue from the following: 2015 2014 2013 Domestic electric and gas revenues (a) $ 5,239 $ 5,209 $ 4,842 U.K. operating revenues (b) 2,410 2,621 2,403 Domestic - other 20 22 18 Total $ 7,669 $ 7,852 $ 7,263 (a) Represents revenues from cost-based rate-regulated generation, transmission and/or distribution in Pennsylvania, Kentucky, Virginia and Tennessee, includ ing regulated wholesale revenue. (b) Primarily represents regulated electricity distribution revenues from the operation of WPD's distribution networks.
Schedule of Valuation and Qualifying Accounts Disclosure	The changes in the allowance for doubtful accounts were: Additions Balance at Charged to Balance at Beginning of Period Charged to Income Other Accounts Deductions (a) End of Period PPL 2015 $ 44 $ 49 $ (2) $ 50 $ 41 2014 43 49 48 44 2013 41 38 4 (b) 40 43 PPL Electric 2015 $ 17 $ 39 $ 40 $ 16 2014 18 34 35 17 2013 18 32 32 18 LKE 2015 $ 25 $ 9 $ (2) $ 9 $ 23 2014 22 14 11 25 2013 19 4 4 (b) 5 22 LG&E 2015 $ 2 $ 2 $ 3 $ 1 2014 2 5 $ (1) (b) 4 2 2013 1 2 1 (b) 2 2 KU 2015 $ 2 $ 5 $ 5 $ 2 2014 4 8 $ (3) (b) 7 2 2013 2 3 3 (b) 4 4 (a) Primarily related to uncollectible accounts written off. (b) Primarily related to capital projects, thus the provision was recorded as an adjustment to construction work in progress .
Schedule of Restricted Cash and Cash Equivalents	At December 31, the balances of restricted cash and cash equivalents included the following. PPL PPL Electric 2015 2014 2015 2014 Low carbon network fund (a) $ 22 $ 19 Other 11 12 $ 2 $ 3 $ 33 $ 31 $ 2 $ 3 ( a ) Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
Capitalized Interest Costs	Capitalized interest, including the debt component of AFUDC for PPL, was as fo llows. PPL 2015 $ 11 2014 16 2013 15
Weighted-average Rates of Depreciation	The f ollowing percentages are the weighted- average annu al rates of depreciation at December 31. 2015 PPL PPL Electric LKE LG&E KU Regulated utility plant 2.57 2.46 3.69 3.65 3.71 2014 PPL PPL Electric LKE LG&E KU Regulated utility plant 2.92 2.46 3.80 4.05 3.63
Schedule of Utility Inventory	"Fuel, materials and supplies" on th e Balance Sheets consisted of the following at December 31. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 Fuel $ 168 $ 166 $ 168 $ 166 $ 71 $ 66 $ 97 $ 100 Natural gas stored underground (a) 42 54 42 54 42 54 Materials and supplies 147 161 88 91 38 42 50 49 Total $ 357 $ 381 $ 298 $ 311 $ 151 $ 162 $ 147 $ 149 (a) The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers .
Balance Sheet Classification of Deferred Taxes	The following table presents the amounts reclassifi ed from current deferred tax assets and liabilities to noncurrent deferred tax liabilities on the balance sheets as of December 31, 2014. Assets Liabilities PPL $ 125 PPL Electric 58 LKE 16 KU 2 Discontinued Operations 8 $ 4
PPL Electric Utilities Corp [Member]
Summary Of Significant Accounting Policies [Line Items]
Schedule of Restricted Cash and Cash Equivalents	At December 31, the balances of restricted cash and cash equivalents included the following. PPL PPL Electric 2015 2014 2015 2014 Low carbon network fund (a) $ 22 $ 19 Other 11 12 $ 2 $ 3 $ 33 $ 31 $ 2 $ 3 ( a ) Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded. 2015 2014 PPL Electric $ 56 $ (25) LKE (10) 136 LG&E 4 74 KU (5) 60
LG And E And KU Energy LLC [Member]
Summary Of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded. 2015 2014 PPL Electric $ 56 $ (25) LKE (10) 136 LG&E 4 74 KU (5) 60
Schedule of Utility Inventory	"Fuel, materials and supplies" on th e Balance Sheets consisted of the following at December 31. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 Fuel $ 168 $ 166 $ 168 $ 166 $ 71 $ 66 $ 97 $ 100 Natural gas stored underground (a) 42 54 42 54 42 54 Materials and supplies 147 161 88 91 38 42 50 49 Total $ 357 $ 381 $ 298 $ 311 $ 151 $ 162 $ 147 $ 149 (a) The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers .
Louisville Gas And Electric Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded. 2015 2014 PPL Electric $ 56 $ (25) LKE (10) 136 LG&E 4 74 KU (5) 60
Schedule of Utility Inventory	"Fuel, materials and supplies" on th e Balance Sheets consisted of the following at December 31. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 Fuel $ 168 $ 166 $ 168 $ 166 $ 71 $ 66 $ 97 $ 100 Natural gas stored underground (a) 42 54 42 54 42 54 Materials and supplies 147 161 88 91 38 42 50 49 Total $ 357 $ 381 $ 298 $ 311 $ 151 $ 162 $ 147 $ 149 (a) The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers .
Kentucky Utilities Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded. 2015 2014 PPL Electric $ 56 $ (25) LKE (10) 136 LG&E 4 74 KU (5) 60
Schedule of Utility Inventory	"Fuel, materials and supplies" on th e Balance Sheets consisted of the following at December 31. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 Fuel $ 168 $ 166 $ 168 $ 166 $ 71 $ 66 $ 97 $ 100 Natural gas stored underground (a) 42 54 42 54 42 54 Materials and supplies 147 161 88 91 38 42 50 49 Total $ 357 $ 381 $ 298 $ 311 $ 151 $ 162 $ 147 $ 149 (a) The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers .

Segment and Related Informati37

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2015
Segment and Related Information [Abstract]
Segment and Related Information	Financial data for the segments are: Income Statement Data 2015 2014 2013 Operating Revenues from external customers (a) U.K. Regulated $ 2,410 $ 2,621 $ 2,403 Kentucky Regulated 3,115 3,168 2,976 Pennsylvania Regulated 2,124 2,044 1,870 Corporate and Other 20 19 14 Total $ 7,669 $ 7,852 $ 7,263 Depreciation U.K. Regulated $ 242 $ 337 $ 300 Kentucky Regulated 382 354 334 Pennsylvania Regulated 214 185 178 Corporate and Other 45 47 31 Total $ 883 $ 923 $ 843 Amortization (b) U.K. Regulated $ 6 $ 17 $ 19 Kentucky Regulated 27 25 22 Pennsylvania Regulated 26 19 19 Corporate and Other 4 6 Total $ 59 $ 65 $ 66 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ (88) $ (199) $ 44 Kentucky Regulated 11 12 12 Total $ (77) $ (187) $ 56 Interest Expense U.K. Regulated $ 417 $ 461 $ 425 Kentucky Regulated 232 219 212 Pennsylvania Regulated 130 122 108 Corporate and Other 92 41 33 Total $ 871 $ 843 $ 778 Income from Continuing Operations Before Income Taxes U.K. Regulated $ 1,249 $ 1,311 $ 993 Kentucky Regulated 547 501 484 Pennsylvania Regulated 416 423 317 Corporate and Other (d) (144) (106) (66) Total $ 2,068 $ 2,129 $ 1,728 Income Taxes (e) U.K. Regulated $ 128 $ 329 $ 71 Kentucky Regulated 221 189 179 Pennsylvania Regulated 164 160 108 Corporate and Other (d) (48) 14 2 Total $ 465 $ 692 $ 360 Deferred income taxes and investment tax credits (f) U.K. Regulated $ 45 $ 94 $ (45) Kentucky Regulated 236 449 254 Pennsylvania Regulated 220 87 127 Corporate and Other (d) (73) 36 51 Total $ 428 $ 666 $ 387 Net Income U.K. Regulated $ 1,121 $ 982 $ 922 Kentucky Regulated 326 312 307 Pennsylvania Regulated 252 263 209 Corporate and Other (d) (96) (120) (68) Discontinued Operations (g) (921) 300 (240) Total $ 682 $ 1,737 $ 1,130 Cash Flow Data 2015 2014 2013 Expenditures for long-lived assets U.K. Regulated $ 1,242 $ 1,438 $ 1,280 Kentucky Regulated 1,210 1,262 1,434 Pennsylvania Regulated 1,107 957 942 Corporate and Other 11 66 26 Total $ 3,570 $ 3,723 $ 3,682 As of December 31, 2015 2014 Balance Sheet Data Total Assets U.K. Regulated $ 16,669 $ 15,944 Kentucky Regulated 13,756 13,022 Pennsylvania Regulated 8,511 7,706 Corporate and Other (h) 365 909 Discontinued Operations 11,025 Total $ 39,301 $ 48,606 (a) See Note 1 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of regulatory assets, debt discounts and premiums, debt issuance costs, emission allowances and RECs. (c) Includes unrealized gains and losses from economic activity. See Note 17 for additional information. (d) 2015 and 2014 include certain costs related to the spinoff of PPL Energy Supply, including deferred income tax expense, transition cost s and separation benefits for PPL Services employees. See Note 8 for additional information. (e) Represents both current and deferred income taxes , including investment tax credits. (f) Represents a non-cash expense item that is also incl uded in "Income Taxes.” (g) 2015 includes an $879 million loss on the spinoff of PPL Energy Supply and five months of Supply segment earnings. 2014 includes a gain of $237 million ($137 million after-tax) on the sale of the Montana hydroelectric gener ating facilities. 2013 includes a charge of $697 million ($413 million after-tax) for the termination of the lease of the Colstrip coal-fired electric generating facility. See Note 8 for additional information on these transactions. (h) Primarily consists of unallocated items, including cash, PP&E and the elimination of inter-segment transactions.
Geographic Data	Financial data for the segments are: 2015 2014 2013 Geographic Data Revenues from external customers U.K. $ 2,410 $ 2,621 $ 2,403 U.S. 5,259 5,231 4,860 Total $ 7,669 $ 7,852 $ 7,263
Long-lived Assets	Financial data for the segments are: As of December 31, 2015 2014 Long-Lived Assets U.K. $ 12,487 $ 11,942 U.S. 18,569 16,890 Total $ 31,056 $ 28,832

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Basic and Diluted EPS Computations	Reconciliations of the amoun ts of income and shares of PPL common stock (in thousands) for the periods ended December 31 used in the EPS calculation are: 2015 2014 2013 Income (Numerator) Income from continuing operations after income taxes $ 1,603 $ 1,437 $ 1,368 Less amounts allocated to participating securities 6 7 7 Income from continuing operations after income taxes available to PPL common shareowners - Basic 1,597 1,430 1,361 Plus interest charges (net of tax) related to Equity Units (a) 9 44 Income from continuing operations after income taxes available to PPL common shareowners - Diluted $ 1,597 $ 1,439 $ 1,405 Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ (921) $ 300 $ (238) Net income $ 682 $ 1,737 $ 1,130 Less amounts allocated to participating securities 2 9 6 Net income available to PPL common shareowners - Basic 680 1,728 1,124 Plus interest charges (net of tax) related to Equity Units (a) 9 44 Net income available to PPL common shareowners - Diluted $ 680 $ 1,737 $ 1,168 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 669,814 653,504 608,983 Add incremental non-participating securities: Share-based payment awards (b) 2,772 1,910 1,062 Equity Units (a) 10,559 52,568 Forward sale agreements and purchase contracts (b) 460 Weighted-average shares - Diluted EPS 672,586 665,973 663,073 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 2.38 $ 2.19 $ 2.24 Income (loss) from discontinued operations (net of income taxes) (1.37) 0.45 (0.39) Net Income $ 1.01 $ 2.64 $ 1.85 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 2.37 $ 2.16 $ 2.12 Income (loss) from discontinued operations (net of income taxes) (1.36) 0.45 (0.36) Net Income $ 1.01 $ 2.61 $ 1.76 (a) In 2014 and 2013, t he If-Converted Method was applied to the Equ ity Units prior to settlement . See Note 7 for additional information on the Equity Units, including the issuance of PPL common stock to settle the Purchase contracts. (b) The Treasury Stock Method was applied to non-participating share-based payment awards and forward sale agreement s.
Common Stock Issuances	For the year ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousan ds): 2015 Stock-based compensation plans (a) 4,853 DRIP 1,728 (a ) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.
Antidilutive Securities Excluded From Diluted EPS	For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive . 2015 2014 2013 Stock options 1,087 1,816 4,446 Performance units 36 5 55 Restricted stock units 31 29

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Taxes [Line Items]
Components of Income (Loss) From Continuing Operations Before Income Taxes	"Income from Continuing Operations Before Income Taxes" inc luded the following . 2015 2014 2013 Domestic income $ 968 $ 922 $ 669 Foreign income 1,100 1,207 1,059 Total $ 2,068 $ 2,129 $ 1,728
Components of Deferred Tax Assets and Liabilities	Significant c omponents of PPL's deferred income tax assets and liabili ties were as follows . 2015 2014 Deferred Tax Assets Deferred investment tax credits $ 50 $ 52 Regulatory obligations 123 131 Accrued pension costs 217 200 Federal loss carryforwards (a) 587 129 State loss carryforwards (b) 319 225 Federal and state tax credit carryforwards 201 196 Foreign capital loss carryforwards 387 446 Foreign loss carryforwards 4 6 Foreign - pensions 171 182 Foreign - regulatory obligations 12 23 Foreign - other 8 11 Contributions in aid of construction 139 138 Domestic - other 209 194 Unrealized losses on qualifying derivatives 15 46 Valuation allowances (b) (662) (622) Total deferred tax assets 1,780 1,357 Deferred Tax Liabilities Domestic plant - net 3,875 3,079 Taxes recoverable through future rates 162 156 Other regulatory assets 332 322 Reacquired debt costs 28 31 Foreign plant - net 777 854 Domestic - other 24 17 Total deferred tax liabilities 5,198 4,459 Net deferred tax liability $ 3,418 $ 3,102 (a ) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments. ( b) Includes $77 million of deferred tax assets related to state loss carryforwards and related valuation allowances previously reflected on the PPL Energy Supply Segment. The deferred tax assets and related valuation allowance remain with PPL after the spino ff.
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, PPL had the following loss and tax cre dit carryforwards . 2015 Expiration Loss carryforwards Federal net operating losses (a) $ 1,660 2029-2035 Federal charitable contributions 15 2020 State net operating losses (a) (b) 5,269 2017-2035 State charitable contributions 34 2016-2020 Foreign net operating losses (c) 21 Indefinite Foreign capital losses (d) 2,152 Indefinite Credit carryforwards Federal investment tax credit 125 2025-2028 Federal alternative minimum tax credit 40 Indefinite Federal - other (e) 29 2016-2035 State - other 5 2022 ( a) Includes an insignificant amount of federal and state net operating loss carryforwards from excess tax deductions related to stock compensation for which a tax benefit will be recorded in Equity when realized. (b) A valuation allowance of $254 million has been recorded against the deferred tax assets for these losse s. (c ) A valuation allowance of $4 million has been recorded against the deferred tax assets for these losses . (d) A valuation allowance of $ 387 million has been reco rded against the deferred tax assets for these losses . (e) A valuation allowance of $ 12 million has been recorded against the deferred tax assets for these credits .
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	The changes in deferred tax valuation allowances were as follows. Additions Balance at Charged to Balance Beginning Charged Other at End of Period to Income Accounts Deductions of Period 2015 $ 622 $ 24 $ 77 (b) $ 61 (a) $ 662 2014 585 57 6 26 622 2013 632 25 72 (a) 585 (a) The reductions of the U.K. statutory income tax rates in 2015 and 2013 resulted in $44 million and $67 million in reductions in deferred tax assets and the corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for more information on the impact of the U.K. Finance Acts 2015 and 2013. (b) Valuation allowance related to deferred tax assets previously reflected on the PPL Energy Supply Segment. The deferred tax assets and related valuation allowance remain with PP L after the spinoff.
Components of Income Tax Expense (Benefit) From Continuing Operations	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Incom e from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (26) $ 18 $ (102) Current - State 25 26 Current - Foreign 89 152 181 Total Current Expense 88 196 79 Deferred - Federal 699 299 259 Deferred - State 68 120 84 Deferred - Foreign 41 96 (53) Total Deferred Expense, excluding operating loss carryforwards 808 515 290 Investment tax credit, net - Federal (4) (5) (5) Tax expense (benefit) of operating loss carryforwards Deferred - Federal (a) (396) 8 14 Deferred - State (31) (22) (18) Total Tax Expense (Benefit) of Operating Loss Carryforwards (427) (14) (4) Total income taxes from continuing operations $ 465 $ 692 $ 360 Total income tax expense - Federal $ 273 $ 320 $ 166 Total income tax expense - State 62 124 66 Total income tax expense - Foreign 130 248 128 Total income taxes from continuing operations $ 465 $ 692 $ 360 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to provision to return adjustments. In the table above, the following income tax expense (benefits) are excluded from income taxes from continuing operations. 2015 2014 2013 Discontinued operations - PPL Energy Supply Segment $ (30) $ 198 $ (180) Stock-based compensation recorded to Additional Paid-in Capital (4) (2) Valuation allowance on state deferred taxes related to issuance costs of Purchase Contracts recorded to Additional Paid-in Capital (2) Other comprehensive income (2) (190) 159 Valuation allowance on state deferred taxes recorded to other comprehensive income (4) (7) Total $ (36) $ 4 $ (32)
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Incom e from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Reconciliation of Income Tax Expense Federal income tax on Income from Continuing Operations Before Income Taxes at statutory tax rate - 35% $ 724 $ 745 $ 605 Increase (decrease) due to: State income taxes, net of federal income tax benefit 31 28 17 Valuation allowance adjustments (a) 24 55 24 Impact of lower U.K. income tax rates (b) (176) (180) (144) U.S. income tax on foreign earnings - net of foreign tax credit (c) 8 63 21 Federal and state tax reserves adjustments (d) (22) (1) (49) Impact of the U.K. Finance Acts on deferred tax balances (b) (91) (1) (97) Depreciation not normalized (5) (7) (8) State deferred tax rate change (e) (1) 15 Interest benefit on U.K. financing entities (20) (5) (7) Other (8) (4) (17) Total increase (decrease) (259) (53) (245) Total income taxes from continuing operations $ 465 $ 692 $ 360 Effective income tax rate 22.5% 32.5% 20.8% (a) During 2015, PPL recorded $24 million of deferred income tax expense related to deferred tax valuation allowances. PPL recorded state deferred income tax expense of $12 million primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized and $12 million of federal deferred income tax expense primarily related to federal tax credit carryforwards that are expected to expire as a result of lower future taxable earnings due to the extension of bonus depr eciation. As a result of the PPL Energy Supply spinoff announcement, PPL recorded $50 million of deferred income tax expense during 2014 to adjust the valuation allowance on deferred tax assets primarily for state net operating loss carryforwards that we re previously supported by the future earnings of PPL Energy Supply. See Note 8 for additional information on the spinoff. During 2013, PPL recorded $23 million of state deferred income tax expense related to a deferred tax valuation allowance primarily due to a decrease in projected future taxable income at PPL Energy Supply over the remaining carryforward period of Pennsylvania net operating losses. (b) The U.K. Finance Act 2015 , enacted in November 2015 , reduced the U.K. statutory income tax rate f rom 20% to 1 9% effective April 1, 2017 and from 19 % to 18% effective April 1, 2020 . As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2015 related to both rate decreases. The U.K. Finance Act 2013, enact ed in July 2013, reduced the U.K. statutory income tax rate from 23% to 21% effective April 1, 2014 and from 21% to 20% effective April 1, 2015. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2013 re lated to both rate decreases. (c) During 2015, PPL recorded lower income taxes primarily attributable to a decrease in taxable dividends. During 2014, PPL recorded $47 million of income tax expense primarily attributable to taxable dividends. During 20 13, PPL recorded $28 million of income tax expense resulting from increased taxable dividends offset by a $19 million income tax benefit associated with a ruling obtained from the IRS impacting the recalculation of 2010 U.K. earnings and profits that was r eflected on an amended 2010 U.S. tax return. (d) In 2015, PPL recorded a $12 million tax benefit related to the settlement of the IRS audit for the tax years 1998-2011. In May 2013, the Supreme Court ruled that the U.K. Windfall Profits Tax (WPT) imposed on privatized utilities, including WPD, is a creditable tax for U.S. federal income tax purposes. As a result of the Supreme Court ruling, PPL recorded a tax benefit of $44 million during 2013, of which $19 million relates to int erest. In 2013, PPL r ecorded a federal and state income tax reserve benefit of $7 million related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization was zero. (e) During each period, PPL recorded adjustments related to its December 31 state deferred tax liabilities as a result of annual changes in state apportionment and the impact on the future estimated state income tax rate .
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Incom e from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Taxes, other than income State gross receipts (a) $ 89 $ 102 $ 98 Foreign property 148 157 147 Domestic Other 62 58 53 Total $ 299 $ 317 $ 298 (a) The decrease in 2015 was primarily due to the settlement of a 2011 gross receipts tax audit resulting in the reversal of $17 million of previously recognized reserves.
Summary of Income Tax Examinations	With few exceptions, at December 31, 2015 , these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows . PPL PPL Electric LKE LG&E KU U.S. (federal) 2011 and prior 2011 and prior 2011 and prior 2011 and prior 2011 and prior Pennsylvania (state) 2011 and prior 2011 and prior Kentucky (state) 2010 and prior 2010 and prior 2010 and prior 2010 and prior U.K. (foreign) 2012 and prior
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of PPL Electric's deferred income tax assets and liabilities were as follows . 2015 2014 Deferred Tax Assets Accrued pension costs $ 92 $ 85 Contributions in aid of construction 111 110 Regulatory obligations 56 39 State loss carryforwards 27 30 Federal loss carryforwards (a) 146 51 Other 87 54 Total deferred tax assets 519 369 Deferred Tax Liabilities Electric utility plant - net 1,803 1,453 Taxes recoverable through future rates 135 132 Reacquired debt costs 18 20 Other regulatory assets 213 173 Other 13 16 Total deferred tax liabilities 2,182 1,794 Net deferred tax liability $ 1,663 $ 1,425 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments .
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, PPL Electric had the following loss carryforwards. 2015 Expiration Loss carryforwards Federal net operating losses $ 411 2031-2035 Federal charitable contributions 3 2020 State net operating losses 410 2030-2032 State charitable contributions 13 2016-2020
Components of Income Tax Expense (Benefit) From Continuing Operations	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (80) $ 60 $ (15) Current - State 23 15 (4) Total Current Expense (Benefit) (57) 75 (19) Deferred - Federal 287 70 109 Deferred - State 12 16 16 Total Deferred Expense, excluding operating loss carryforwards 299 86 125 Investment tax credit, net - Federal (1) (1) Tax expense (benefit) of operating loss carryforwards Deferred - Federal (75) 4 Deferred - State (3) (1) Total Tax Expense (Benefit) of Operating Loss Carryforwards (78) 3 Total income tax expense $ 164 $ 160 $ 108 Total income tax expense - Federal $ 132 $ 129 $ 97 Total income tax expense - State 32 31 11 Total income tax expense $ 164 $ 160 $ 108
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 146 $ 148 $ 111 Increase (decrease) due to: State income taxes, net of federal income tax benefit 25 22 16 Federal and state tax reserves adjustments (a) 2 (1) (9) Federal and state income tax return adjustments (2) 1 (1) Depreciation not normalized (4) (6) (6) Other (3) (4) (3) Total increase (decrease) 18 12 (3) Total income tax expense $ 164 $ 160 $ 108 Effective income tax rate 39.4% 37.8% 34.1% (a) PPL Electric recorded a tax benefit of $7 million during 2013 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization wa s zero.
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows. 2015 2014 2013 Taxes, other than income State gross receipts (a) $ 89 $ 102 $ 98 Property and other 5 5 5 Total $ 94 $ 107 $ 103 (a) The decrease in 2015 was primarily due to the settlement of a 2011 gross receipts tax audit resulting in the reversal of $17 million of previously recognized reserves.
LG And E And KU Energy LLC [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of LKE's deferred income tax assets and liabilities were as follows. 2015 2014 Deferred Tax Assets Federal loss carryforwards (a) $ 280 $ 46 State loss carryforwards 35 36 Tax credit carryforwards 181 182 Regulatory liabilities 66 92 Accrued pension costs 53 53 Income taxes due to customers 17 20 Deferred investment tax credits 50 51 Derivative liability 18 45 Other 55 44 Valuation allowances (12) Total deferred tax assets 743 569 Deferred Tax Liabilities Plant - net 2,076 1,639 Regulatory assets 119 143 Other 11 12 Total deferred tax liabilities 2,206 1,794 Net deferred tax liability $ 1,463 $ 1,225 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments .
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, LKE had the following loss and tax credit carryforwards . 2015 Expiration Loss carryforwards Federal net operating losses $ 801 2029-2035 State net operating losses 934 2028-2035 State capital losses 1 2016 Credit carryforwards Federal investment tax credit 125 2025-2028 Federal alternative minimum tax credit 28 Indefinite Federal - other 27 2016-2035 State - other 5 2022
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	Changes in deferred tax valuation allowances were : Balance at Balance Beginning at End of Period Additions Deductions of Period 2015 $ 12 (a) $ 12 2014 $ 4 $ 4 (b) 2013 5 1 (b) 4 (a) Represents tax credits expiring in 2016 through 2020 that are more likely than not to expire before being utilized. (b) Primarily related to the expiration of state capital loss carryforwards .
Components of Income Tax Expense (Benefit) From Continuing Operations	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ 2 $ (247) $ (59) Current - State 1 8 10 Total Current Expense (Benefit) 3 (239) (49) Deferred - Federal 405 437 244 Deferred - State 32 23 20 Total Deferred Expense, excluding benefits of operating loss carryforwards 437 460 264 Investment tax credit, net - Federal (3) (4) (4) Tax benefit of operating loss carryforwards Deferred - Federal (198) (8) (4) Deferred - State (1) Total Tax Benefit of Operating Loss Carryforwards (198) (8) (5) Total income tax expense from continuing operations (a) $ 239 $ 209 $ 206 Total income tax expense - Federal $ 206 $ 178 $ 177 Total income tax expense - State 33 31 29 Total income tax expense from continuing operations (a) $ 239 $ 209 $ 206 ( a) Excludes current and deferred federal and state tax expense (benefit) recorded to Discontinued Operations of less than $1 million in 2015 and 2014, and $1 million in 201 3. Also, e xcludes deferred federal and state tax expense (benefit) recorded to OCI of less than $( 1) million in 2015, $(36) million in 2014 and $18 million in 201 3.
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 211 $ 194 $ 193 Increase (decrease) due to: State income taxes, net of federal income tax benefit 22 20 20 Amortization of investment tax credit (3) (4) (4) Valuation allowance adjustment (a) 12 Other (3) (1) (3) Total increase (decrease) 28 15 13 Total income tax expense from continuing operations $ 239 $ 209 $ 206 Effective income tax rate 39.6% 37.8% 37.4% ( a) Represents a valuation allowance against tax credits expiring from 2016 through 2020 that are more likely than not to expire before being utilized.
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2015 2014 2013 Taxes, other than income Property and other $ 57 $ 52 $ 48 Total $ 57 $ 52 $ 48
Louisville Gas And Electric Co [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of LG&E's deferred income tax assets and liabilities were as follows. 2015 2014 Deferred Tax Assets Federal loss carryforwards (a) $ 76 Regulatory liabilities 38 $ 51 Deferred investment tax credits 13 14 Income taxes due to customers 17 18 Derivative liability 18 32 Other 15 9 Total deferred tax assets 177 124 Deferred Tax Liabilities Plant - net 896 698 Regulatory assets 75 90 Accrued pension costs 28 28 Other 7 8 Total deferred tax liabilities 1,006 824 Net deferred tax liability $ 829 $ 700 (a) Increase in Federal loss carryforwards primarily relates to the e xtension of bonus depreciation.
Components of Income Tax Expense (Benefit) From Continuing Operations	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (15) $ (25) $ 52 Current - State 3 10 16 Total Current Expense (Benefit) (12) (15) 68 Deferred - Federal 190 114 33 Deferred - State 13 6 (2) Total Deferred Expense, excluding benefits of operating loss carryforwards 203 120 31 Investment tax credit, net - Federal (1) (2) (2) Tax benefit of operating loss carryforwards Deferred - Federal (76) (3) Total Tax Benefit of Operating Loss Carryforwards (76) (3) Total income tax expense $ 114 $ 103 $ 94 Total income tax expense - Federal $ 98 $ 87 $ 80 Total income tax expense - State 16 16 14 Total income tax expense $ 114 $ 103 $ 94
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 105 $ 95 $ 90 Increase (decrease) due to: State income taxes, net of federal income tax benefit 11 10 10 Amortization of investment tax credit (1) (2) (2) Other (1) (4) Total increase (decrease) 9 8 4 Total income tax expense $ 114 $ 103 $ 94 Effective income tax rate 38.1% 37.9% 36.6%
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Taxes, other than income Property and other $ 28 $ 25 $ 24 Total $ 28 $ 25 $ 24
Kentucky Utilities Co [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of KU's deferre d income tax assets and liabilities were as follows . 2015 2014 Deferred Tax Assets Federal loss carryforwards (a) $ 97 Regulatory liabilities 28 $ 41 Deferred investment tax credits 36 37 Income taxes due to customers 2 Derivative liability 13 Other 7 7 Total deferred tax assets 168 100 Deferred Tax Liabilities Plant - net 1,164 922 Regulatory assets 44 53 Other 6 7 Total deferred tax liabilities 1,214 982 Net deferred tax liability $ 1,046 $ 882 (a) Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation.
Components of Income Tax Expense (Benefit) From Continuing Operations	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Income Tax Expense (Benefit) Current - Federal $ (21) $ (95) $ 51 Current - State 1 6 12 Total Current Expense (Benefit) (20) (89) 63 Deferred - Federal 240 212 66 Deferred - State 19 14 8 Total Deferred Expense, excluding benefits of operating loss carryforwards 259 226 74 Investment tax credit, net - Federal (2) (2) (2) Tax benefit of operating loss carryforwards Deferred - Federal (97) (3) Total Tax Benefit of Operating Loss Carryforwards (97) (3) Total income tax expense (a) $ 140 $ 135 $ 132 Total income tax expense - Federal $ 120 $ 115 $ 112 Total income tax expense - State 20 20 20 Total income tax expense (a) $ 140 $ 135 $ 132 (a) Excludes deferred federal and state tax expense (benefit) recorded to OCI of less than $(1) million in 2015, 2014 and 2013 .
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Reconciliation of Income Taxes Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 131 $ 124 $ 126 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 13 14 Amortization of investment tax credit (2) (2) (2) Other (2) (6) Total increase (decrease) 9 11 6 Total income tax expense $ 140 $ 135 $ 132 Effective income tax rate 37.4% 38.0% 36.7%
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to " Income Before Income Taxes " to income taxes for reporting purposes, and details of " Taxes, other than income " were: 2015 2014 2013 Taxes, other than income Property and other $ 29 $ 27 $ 24 Total $ 29 $ 27 $ 24

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2015
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31. PPL PPL Electric 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 Gas supply clause 1 15 Transmission service charge 10 6 $ 10 $ 6 Other 13 11 3 6 Total current regulatory assets (a) $ 48 $ 37 $ 13 $ 12 Noncurrent Regulatory Assets: Defined benefit plans $ 809 $ 720 $ 469 $ 372 Taxes recoverable through future rates 326 316 326 316 Storm costs 93 124 30 46 Unamortized loss on debt 68 77 42 49 Interest rate swaps 141 122 Accumulated cost of removal of utility plant 137 114 137 114 AROs 143 79 Other 16 10 2 Total noncurrent regulatory assets $ 1,733 $ 1,562 $ 1,006 $ 897 Current Regulatory Liabilities: Generation supply charge $ 41 $ 28 $ 41 $ 28 Demand side management 8 2 Gas supply clause 6 6 Transmission formula rate 48 42 48 42 Fuel adjustment clause 14 Storm damage expense 16 3 16 3 Other 12 10 8 3 Total current regulatory liabilities $ 145 $ 91 $ 113 $ 76 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 Coal contracts (b) 17 59 Power purchase agreement - OVEC (b) 83 92 Net deferred tax assets 23 26 Act 129 compliance rider 22 18 $ 22 $ 18 Defined benefit plans 24 16 Interest rate swaps 82 84 Other 3 4 Total noncurrent regulatory liabilities $ 945 $ 992 $ 22 $ 18 LKE LG&E KU 2015 2014 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 $ 13 $ 4 $ 11 $ 1 Gas supply clause 1 15 1 15 Fuel adjustment clause 4 2 2 Gas line tracker 1 1 Other 9 1 1 8 1 Total current regulatory assets $ 35 $ 25 $ 16 $ 21 $ 19 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 340 $ 348 $ 215 $ 215 $ 125 $ 133 Storm costs 63 78 35 43 28 35 Unamortized loss on debt 26 28 17 18 9 10 Interest rate swaps 141 122 98 89 43 33 AROs 143 79 57 28 86 51 Plant retirement costs 6 6 Other 8 10 2 4 6 6 Total noncurrent regulatory assets $ 727 $ 665 $ 424 $ 397 $ 303 $ 268 Current Regulatory Liabilities: Demand side management $ 8 $ 2 $ 4 $ 1 $ 4 $ 1 Gas supply clause 6 6 6 6 Fuel adjustment clause 14 2 12 Gas line tracker 3 3 Other 4 4 1 3 4 Total current regulatory liabilities $ 32 $ 15 $ 13 $ 10 $ 19 $ 5 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 $ 301 $ 302 $ 390 $ 391 Coal contracts (b) 17 59 7 25 10 34 Power purchase agreement - OVEC (b) 83 92 57 63 26 29 Net deferred tax assets 23 26 23 24 2 Defined benefit plans 24 16 24 16 Interest rate swaps 82 84 41 42 41 42 Other 3 4 2 2 1 2 Total noncurrent regulatory liabilities $ 923 $ 974 $ 431 $ 458 $ 492 $ 516 (a ) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. ( b ) These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acq uisition of LKE by PPL.
PPL Electric Utilities Corp [Member]
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31. PPL PPL Electric 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 Gas supply clause 1 15 Transmission service charge 10 6 $ 10 $ 6 Other 13 11 3 6 Total current regulatory assets (a) $ 48 $ 37 $ 13 $ 12 Noncurrent Regulatory Assets: Defined benefit plans $ 809 $ 720 $ 469 $ 372 Taxes recoverable through future rates 326 316 326 316 Storm costs 93 124 30 46 Unamortized loss on debt 68 77 42 49 Interest rate swaps 141 122 Accumulated cost of removal of utility plant 137 114 137 114 AROs 143 79 Other 16 10 2 Total noncurrent regulatory assets $ 1,733 $ 1,562 $ 1,006 $ 897 Current Regulatory Liabilities: Generation supply charge $ 41 $ 28 $ 41 $ 28 Demand side management 8 2 Gas supply clause 6 6 Transmission formula rate 48 42 48 42 Fuel adjustment clause 14 Storm damage expense 16 3 16 3 Other 12 10 8 3 Total current regulatory liabilities $ 145 $ 91 $ 113 $ 76 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 Coal contracts (b) 17 59 Power purchase agreement - OVEC (b) 83 92 Net deferred tax assets 23 26 Act 129 compliance rider 22 18 $ 22 $ 18 Defined benefit plans 24 16 Interest rate swaps 82 84 Other 3 4 Total noncurrent regulatory liabilities $ 945 $ 992 $ 22 $ 18 LKE LG&E KU 2015 2014 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 $ 13 $ 4 $ 11 $ 1 Gas supply clause 1 15 1 15 Fuel adjustment clause 4 2 2 Gas line tracker 1 1 Other 9 1 1 8 1 Total current regulatory assets $ 35 $ 25 $ 16 $ 21 $ 19 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 340 $ 348 $ 215 $ 215 $ 125 $ 133 Storm costs 63 78 35 43 28 35 Unamortized loss on debt 26 28 17 18 9 10 Interest rate swaps 141 122 98 89 43 33 AROs 143 79 57 28 86 51 Plant retirement costs 6 6 Other 8 10 2 4 6 6 Total noncurrent regulatory assets $ 727 $ 665 $ 424 $ 397 $ 303 $ 268 Current Regulatory Liabilities: Demand side management $ 8 $ 2 $ 4 $ 1 $ 4 $ 1 Gas supply clause 6 6 6 6 Fuel adjustment clause 14 2 12 Gas line tracker 3 3 Other 4 4 1 3 4 Total current regulatory liabilities $ 32 $ 15 $ 13 $ 10 $ 19 $ 5 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 $ 301 $ 302 $ 390 $ 391 Coal contracts (b) 17 59 7 25 10 34 Power purchase agreement - OVEC (b) 83 92 57 63 26 29 Net deferred tax assets 23 26 23 24 2 Defined benefit plans 24 16 24 16 Interest rate swaps 82 84 41 42 41 42 Other 3 4 2 2 1 2 Total noncurrent regulatory liabilities $ 923 $ 974 $ 431 $ 458 $ 492 $ 516
LG And E And KU Energy LLC [Member]
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31. PPL PPL Electric 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 Gas supply clause 1 15 Transmission service charge 10 6 $ 10 $ 6 Other 13 11 3 6 Total current regulatory assets (a) $ 48 $ 37 $ 13 $ 12 Noncurrent Regulatory Assets: Defined benefit plans $ 809 $ 720 $ 469 $ 372 Taxes recoverable through future rates 326 316 326 316 Storm costs 93 124 30 46 Unamortized loss on debt 68 77 42 49 Interest rate swaps 141 122 Accumulated cost of removal of utility plant 137 114 137 114 AROs 143 79 Other 16 10 2 Total noncurrent regulatory assets $ 1,733 $ 1,562 $ 1,006 $ 897 Current Regulatory Liabilities: Generation supply charge $ 41 $ 28 $ 41 $ 28 Demand side management 8 2 Gas supply clause 6 6 Transmission formula rate 48 42 48 42 Fuel adjustment clause 14 Storm damage expense 16 3 16 3 Other 12 10 8 3 Total current regulatory liabilities $ 145 $ 91 $ 113 $ 76 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 Coal contracts (b) 17 59 Power purchase agreement - OVEC (b) 83 92 Net deferred tax assets 23 26 Act 129 compliance rider 22 18 $ 22 $ 18 Defined benefit plans 24 16 Interest rate swaps 82 84 Other 3 4 Total noncurrent regulatory liabilities $ 945 $ 992 $ 22 $ 18 LKE LG&E KU 2015 2014 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 $ 13 $ 4 $ 11 $ 1 Gas supply clause 1 15 1 15 Fuel adjustment clause 4 2 2 Gas line tracker 1 1 Other 9 1 1 8 1 Total current regulatory assets $ 35 $ 25 $ 16 $ 21 $ 19 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 340 $ 348 $ 215 $ 215 $ 125 $ 133 Storm costs 63 78 35 43 28 35 Unamortized loss on debt 26 28 17 18 9 10 Interest rate swaps 141 122 98 89 43 33 AROs 143 79 57 28 86 51 Plant retirement costs 6 6 Other 8 10 2 4 6 6 Total noncurrent regulatory assets $ 727 $ 665 $ 424 $ 397 $ 303 $ 268 Current Regulatory Liabilities: Demand side management $ 8 $ 2 $ 4 $ 1 $ 4 $ 1 Gas supply clause 6 6 6 6 Fuel adjustment clause 14 2 12 Gas line tracker 3 3 Other 4 4 1 3 4 Total current regulatory liabilities $ 32 $ 15 $ 13 $ 10 $ 19 $ 5 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 $ 301 $ 302 $ 390 $ 391 Coal contracts (b) 17 59 7 25 10 34 Power purchase agreement - OVEC (b) 83 92 57 63 26 29 Net deferred tax assets 23 26 23 24 2 Defined benefit plans 24 16 24 16 Interest rate swaps 82 84 41 42 41 42 Other 3 4 2 2 1 2 Total noncurrent regulatory liabilities $ 923 $ 974 $ 431 $ 458 $ 492 $ 516
Louisville Gas And Electric Co [Member]
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31. PPL PPL Electric 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 Gas supply clause 1 15 Transmission service charge 10 6 $ 10 $ 6 Other 13 11 3 6 Total current regulatory assets (a) $ 48 $ 37 $ 13 $ 12 Noncurrent Regulatory Assets: Defined benefit plans $ 809 $ 720 $ 469 $ 372 Taxes recoverable through future rates 326 316 326 316 Storm costs 93 124 30 46 Unamortized loss on debt 68 77 42 49 Interest rate swaps 141 122 Accumulated cost of removal of utility plant 137 114 137 114 AROs 143 79 Other 16 10 2 Total noncurrent regulatory assets $ 1,733 $ 1,562 $ 1,006 $ 897 Current Regulatory Liabilities: Generation supply charge $ 41 $ 28 $ 41 $ 28 Demand side management 8 2 Gas supply clause 6 6 Transmission formula rate 48 42 48 42 Fuel adjustment clause 14 Storm damage expense 16 3 16 3 Other 12 10 8 3 Total current regulatory liabilities $ 145 $ 91 $ 113 $ 76 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 Coal contracts (b) 17 59 Power purchase agreement - OVEC (b) 83 92 Net deferred tax assets 23 26 Act 129 compliance rider 22 18 $ 22 $ 18 Defined benefit plans 24 16 Interest rate swaps 82 84 Other 3 4 Total noncurrent regulatory liabilities $ 945 $ 992 $ 22 $ 18 LKE LG&E KU 2015 2014 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 $ 13 $ 4 $ 11 $ 1 Gas supply clause 1 15 1 15 Fuel adjustment clause 4 2 2 Gas line tracker 1 1 Other 9 1 1 8 1 Total current regulatory assets $ 35 $ 25 $ 16 $ 21 $ 19 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 340 $ 348 $ 215 $ 215 $ 125 $ 133 Storm costs 63 78 35 43 28 35 Unamortized loss on debt 26 28 17 18 9 10 Interest rate swaps 141 122 98 89 43 33 AROs 143 79 57 28 86 51 Plant retirement costs 6 6 Other 8 10 2 4 6 6 Total noncurrent regulatory assets $ 727 $ 665 $ 424 $ 397 $ 303 $ 268 Current Regulatory Liabilities: Demand side management $ 8 $ 2 $ 4 $ 1 $ 4 $ 1 Gas supply clause 6 6 6 6 Fuel adjustment clause 14 2 12 Gas line tracker 3 3 Other 4 4 1 3 4 Total current regulatory liabilities $ 32 $ 15 $ 13 $ 10 $ 19 $ 5 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 $ 301 $ 302 $ 390 $ 391 Coal contracts (b) 17 59 7 25 10 34 Power purchase agreement - OVEC (b) 83 92 57 63 26 29 Net deferred tax assets 23 26 23 24 2 Defined benefit plans 24 16 24 16 Interest rate swaps 82 84 41 42 41 42 Other 3 4 2 2 1 2 Total noncurrent regulatory liabilities $ 923 $ 974 $ 431 $ 458 $ 492 $ 516
Kentucky Utilities Co [Member]
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31. PPL PPL Electric 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 Gas supply clause 1 15 Transmission service charge 10 6 $ 10 $ 6 Other 13 11 3 6 Total current regulatory assets (a) $ 48 $ 37 $ 13 $ 12 Noncurrent Regulatory Assets: Defined benefit plans $ 809 $ 720 $ 469 $ 372 Taxes recoverable through future rates 326 316 326 316 Storm costs 93 124 30 46 Unamortized loss on debt 68 77 42 49 Interest rate swaps 141 122 Accumulated cost of removal of utility plant 137 114 137 114 AROs 143 79 Other 16 10 2 Total noncurrent regulatory assets $ 1,733 $ 1,562 $ 1,006 $ 897 Current Regulatory Liabilities: Generation supply charge $ 41 $ 28 $ 41 $ 28 Demand side management 8 2 Gas supply clause 6 6 Transmission formula rate 48 42 48 42 Fuel adjustment clause 14 Storm damage expense 16 3 16 3 Other 12 10 8 3 Total current regulatory liabilities $ 145 $ 91 $ 113 $ 76 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 Coal contracts (b) 17 59 Power purchase agreement - OVEC (b) 83 92 Net deferred tax assets 23 26 Act 129 compliance rider 22 18 $ 22 $ 18 Defined benefit plans 24 16 Interest rate swaps 82 84 Other 3 4 Total noncurrent regulatory liabilities $ 945 $ 992 $ 22 $ 18 LKE LG&E KU 2015 2014 2015 2014 2015 2014 Current Regulatory Assets: Environmental cost recovery $ 24 $ 5 $ 13 $ 4 $ 11 $ 1 Gas supply clause 1 15 1 15 Fuel adjustment clause 4 2 2 Gas line tracker 1 1 Other 9 1 1 8 1 Total current regulatory assets $ 35 $ 25 $ 16 $ 21 $ 19 $ 4 Noncurrent Regulatory Assets: Defined benefit plans $ 340 $ 348 $ 215 $ 215 $ 125 $ 133 Storm costs 63 78 35 43 28 35 Unamortized loss on debt 26 28 17 18 9 10 Interest rate swaps 141 122 98 89 43 33 AROs 143 79 57 28 86 51 Plant retirement costs 6 6 Other 8 10 2 4 6 6 Total noncurrent regulatory assets $ 727 $ 665 $ 424 $ 397 $ 303 $ 268 Current Regulatory Liabilities: Demand side management $ 8 $ 2 $ 4 $ 1 $ 4 $ 1 Gas supply clause 6 6 6 6 Fuel adjustment clause 14 2 12 Gas line tracker 3 3 Other 4 4 1 3 4 Total current regulatory liabilities $ 32 $ 15 $ 13 $ 10 $ 19 $ 5 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 691 $ 693 $ 301 $ 302 $ 390 $ 391 Coal contracts (b) 17 59 7 25 10 34 Power purchase agreement - OVEC (b) 83 92 57 63 26 29 Net deferred tax assets 23 26 23 24 2 Defined benefit plans 24 16 24 16 Interest rate swaps 82 84 41 42 41 42 Other 3 4 2 2 1 2 Total noncurrent regulatory liabilities $ 923 $ 974 $ 431 $ 458 $ 492 $ 516

Financing Activities (Tables)

Financing Activities (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Line Items]
Credit Facilities in Place at Period End	The following credit facilities were in place at: December 31, 2015 December 31, 2014 Letters of Letters of Credit Credit and and Commercial Commercial Expiration Paper Unused Paper Date Capacity Borrowed Issued Capacity Borrowed Issued PPL U.K. WPD plc Syndicated Credit Facility (a) (c) Dec. 2016 £ 210 £ 133 £ 77 £ 103 WPD (South West) Syndicated Credit Facility (a) (c) July 2020 245 245 WPD (East Midlands) Syndicated Credit Facility (a) (c) July 2020 300 300 64 WPD (West Midlands) Syndicated Credit Facility (a) (c) July 2020 300 300 Uncommitted Credit Facilities 40 £ 4 36 £ 5 Total U.K. Credit Facilities (b) £ 1,095 £ 133 £ 4 £ 958 £ 167 £ 5 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Nov. 2018 $ 300 $ 151 $ 149 Syndicated Credit Facility (c) (d) July 2019 300 300 Bilateral Credit Facility (c) (d) Mar. 2016 150 20 130 $ 21 Total PPL Capital Funding Credit Facilities $ 750 $ 471 $ 279 $ 21 PPL Electric Syndicated Credit Facility (c) (d) July 2019 $ 300 $ 1 $ 299 $ 1 LKE Syndicated Credit Facility (c) (d) (f) Oct. 2018 $ 75 $ 75 $ 75 LG&E Syndicated Credit Facility (c) (d) July 2019 $ 500 $ 142 $ 358 $ 264 KU Syndicated Credit Facility (c) (d) July 2019 $ 400 $ 48 $ 352 $ 236 Letter of Credit Facility (c) (d) (e) Oct. 2017 198 198 198 Total KU Credit Facilities $ 598 $ 246 $ 352 $ 434 (a ) The facilities contain financial covenants to maintain an interest coverage ratio of not less than 3.0 times consolidated earnings before income taxes, depreciation and amortization and total net debt not in excess of 85% of its RAV, calculated in accordance with the credit facility. (b) WPD plc's amounts borrowed at December 31, 2015 and 2014 were USD-denominated borrowings of $ 200 million and $ 161 million, which bore interest at 1.83% and 1.86% . WPD (East Midlands) amount borrowed at December 31, 2014 was a GBP-denominated borrowing which equated to $ 100 million and bore interest at 1.00% . At December 31, 2015 , the unused capacity under the U.K. credit facilities was approximately $ 1.4 billion . ( c ) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin. (d) The facilities contain a financial covenant requiring debt to total capitalizati on not to exceed 70% for PPL Capital Funding, PPL Electric, LKE, LG&E and KU, as calculated in accordance with the facilities and other customary covenants . Additionally, as it relates to the syndicated and bilateral cre dit facilities and subject to certain conditions, PPL Capital Funding may request that the capacity of its facility expiring in July 2019 be increased by up to $ 100 million and the facilities expiring in November 2018 and March 2016 may be increased by up to $ 30 million, PPL Electric, LG&E and KU each may request up to a $ 100 million increase in its fac ility's capacity and LKE may request up to a $ 25 million increase in its facility's capacity. (e) KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted t o loans rather than requiring immediate payment. (f) At December 31, 2015 , LKE's interest rate on outstanding borrowings was 1.68% . At December 31, 2014 , LKE’s interest rate on outstanding borrowings was 1.67% .
Commercial paper	The following commercial paper programs were in place a t: December 31, 2015 December 31, 2014 Weighted - Commercial Weighted - Commercial Average Paper Unused Average Paper Interest Rate Capacity Issuances Capacity Interest Rate Issuances PPL Capital Funding 0.78% $ 600 $ 451 $ 149 PPL Electric 300 300 LG&E 0.71% 350 142 208 0.42% $ 264 KU 0.72% 350 48 302 0.49% 236 Total $ 1,600 $ 641 $ 959 $ 500
Long-term Debt	Long-term Debt ( All Registrants ) Weighted-Average December 31, Rate (g) Maturities (g) 2015 2014 PPL U.S. Senior Unsecured Notes 3.87% 2018 - 2044 $ 3,425 $ 3,825 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.97% 2016 - 2045 6,874 6,074 Junior Subordinated Notes 6.31% 2067 - 2073 930 930 Total U.S. Long-term Debt 11,229 10,829 U.K. Senior Unsecured Notes (d) 5.33% 2016 - 2040 7,170 6,627 Index-linked Senior Unsecured Notes (e) 1.82% 2043 - 2056 772 732 Total U.K. Long-term Debt (f) 7,942 7,359 Total Long-term Debt Before Adjustments 19,171 18,188 Fair market value adjustments 30 37 Unamortized premium and (discount), net (e) (28) (52) Unamortized debt issuance costs (125) (119) Total Long-term Debt 19,048 18,054 Less current portion of Long-term Debt 485 1,000 Total Long-term Debt, noncurrent $ 18,563 $ 17,054 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.50% 2020 - 2045 $ 2,864 $ 2,614 Total Long-term Debt Before Adjustments 2,864 2,614 Unamortized discount (13) (12) Unamortized debt issuance costs (23) (21) Total Long-term Debt 2,828 2,581 Less current portion of Long-term Debt 100 Total Long-term Debt, noncurrent $ 2,828 $ 2,481 LKE Senior Unsecured Notes 3.97% 2020 - 2021 $ 725 $ 1,125 First Mortgage Bonds (a) (c) 3.58% 2016 - 2045 4,010 3,460 Long-term debt to affiliate 3.50% 2025 400 Total Long-term Debt Before Adjustments 5,135 4,585 Fair market value adjustments (1) (1) Unamortized discount (16) (17) Unamortized debt issuance costs (30) (24) Total Long-term Debt 5,088 4,543 Less current portion of Long-term Debt 25 900 Total Long-term Debt, noncurrent $ 5,063 $ 3,643 LG&E First Mortgage Bonds (a) (c) 3.36% 2016 - 2045 $ 1,659 $ 1,359 Total Long-term Debt Before Adjustments 1,659 1,359 Fair market value adjustments (1) (1) Unamortized discount (4) (5) Unamortized debt issuance costs (12) (8) Total Long-term Debt 1,642 1,345 Less current portion of Long-term Debt 25 250 Total Long-term Debt, noncurrent $ 1,617 $ 1,095 KU First Mortgage Bonds (a) (c) 3.74% 2020 - 2045 $ 2,351 $ 2,101 Total Long-term Debt Before Adjustments 2,351 2,101 Unamortized discount (10) (10) Unamortized debt issuance costs (15) (12) Total Long-term Debt 2,326 2,079 Less current portion of Long-term Debt 250 Total Long-term Debt, noncurrent $ 2,326 $ 1,829 (a ) Includ e s PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric 's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $ 6.7 billion and $ 5.8 billion at December 31, 2015 and 2014 . Includes LG&E's first m ortgage bonds that are secured by the lien of t he LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $ 4.2 billion and $ 3.7 billion at December 31, 2015 and 2014 . Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substan tially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $ 5.7 billion and $ 5.5 billion at December 31, 2015 and 2014 . (b ) Includes PPL Electric 's series of senior secured bonds that secure its obligations to make payments with respect to each se ries of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same inte rest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indentur e and are secured as noted in (a ) above. This amount includes $ 224 million that may be rede emed at par beginning in 2015 and $ 90 million that may be redeemed, in whole or in part, at par beginning in October 2020 and are subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes. (c) Includes LG&E 's and KU 's series of first mortgage bonds that were issued to the respective trustee s of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amount s , contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in ( a ) above. The related tax-exempt revenue bonds wer e issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate . At December 31, 2015 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $ 418 million for LKE, comprised of $ 391 million and $ 27 million for LG&E and KU , respectively . At December 31, 2015 , the aggregate tax-exempt revenue bonds issued on be half of LG&E and KU that were in a variable rate mode totaled $ 507 million for LKE, comprised of $ 183 million and $ 324 million for LG&E and KU , respectively . Several series of the tax-exempt revenue bonds are insured by monoline bond insurers whose ratings were reduced due to exposures relating to insurance of sub-prime mortgages. Of the bonds outstanding, $ 231 million are in the form of insured auction rate securities ($ 135 million for LG&E and $ 96 million for KU) , wherein interest rates are reset either weekly or every 35 days via an auction proces s. Beginning in late 2007, the interest rates on these insured bonds began to increase due to investor concerns about the creditworthiness of the bond insurers. During 2008, interest rates increased, and LG&E and KU experienced failed auctions when there were insufficient bids for the bonds. When a failed auction occurs, the interest rate is set pursuant to a formula stipulated in the indenture. As noted above, the instruments governing these auction rate bonds permit LG&E and KU to convert the bonds to other interest rate modes. Certain of the variable rate tax-exempt revenue bonds totaling $ 251 million at December 31, 2015 ($ 23 million for LG&E and $ 228 million for KU) , are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events. ( d ) I ncludes £ 225 million ($ 339 million at December 31, 2015 ) of notes that may be redeemed, in total but not in part, on December 21, 2026 , at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. G overnment bond. ( e ) The principal amount of the notes issued by WPD (South West) and WPD (East Midlands) is adjusted based on changes in a specified index, as detailed in the terms of the related indentures. The adjustment to the princi pal amount s from 2014 to 2015 was an increase of approximately £ 4 million ($ 6 million) resulting from inflation . In addition, this amount includes £ 225 million ($ 339 million at Decembe r 31, 2015 ) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026 , at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nomina ted U.K. government bond. (f) I ncludes £ 4.4 billion ($ 6.6 billion at December 31, 2015 ) of notes tha t may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the n otes are withdrawn by any of the rating agencies (Moody's or S&P) or reduced to a non-investment grade rating of Ba1 or BB+ or lower in connection with a restructu ring event which includes the loss of, or a material adverse change to, the distribution license s under which the issuer operate s . (g) The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2015 .
Long-term Debt Maturities	The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2016 through 2020 and thereafter are as follows: PPL PPL Electric LKE LG&E KU 2016 $ 485 $ 25 $ 25 2017 294 194 194 2018 348 98 98 2019 40 40 40 2020 1,301 $ 100 975 $ 500 Thereafter 16,703 2,764 3,803 1,302 1,851 Total $ 19,171 $ 2,864 $ 5,135 $ 1,659 $ 2,351

Acquisitions, Development and42

Acquisitions, Development and Divestures (Tables)	12 Months Ended
	Dec. 31, 2015
Acquisitions, Development and Divestitures [Line Items]
Components of Discontinued Operations	The following table summarizes PPL's fair value analys is: Weighted Fair Value Approach Weighting (in billions) Talen Energy Market Value 50% $ 1.4 Income/Discounted Cash Flow 30% 1.1 Alternative Market (Comparable Company) 20% 0.7 Estimated Fair Value $ 3.2 Following are the components of Discontinued Operations in the Statements of Income for the periods ended December 31: 2015 2014 2013 Operating revenues $ 1,427 $ 3,848 $ 4,648 Operating expenses 1,328 3,410 4,173 Other Income (Expense) - net (21) 13 32 Interest expense (a) 150 190 228 Gain on sale of Montana Hydro Sale 237 Loss on lease termination (697) Income tax expense (benefit) (30) 198 (180) Loss on spinoff (879) Income (Loss) from Discontinued Operations (net of income taxes) $ (921) $ 300 $ (238) (a) Includes interest associated with the Supply segment with no additional allocation as the Supply segment was sufficiently capitalized. The following major classes of assets and liabilities were dis tributed and removed from PPL's Balance Sheet on June 1, 2015. Additionally, the following major classes of assets and liabilities were reclassified to discontinued operations as of December 31, 2014: Discontinued Distribution on Operations at June 1, December 31, 2015 2014 Cash and cash equivalents (a) $ 371 $ 352 Restricted cash and cash equivalents 156 176 Accounts receivable and unbilled revenues 334 504 Fuels, materials and supplies 415 455 Price risk management assets 784 1,079 Other current assets 46 26 Total Current Assets 2,106 2,592 Investments 999 980 PP&E, net 6,384 6,428 Goodwill 338 338 Other intangibles 260 257 Price risk management assets 244 239 Other noncurrent assets 63 69 Total Noncurrent Assets 8,288 8,311 Total assets $ 10,394 $ 10,903 Short-term debt and long-term debt due within one year $ 885 $ 1,165 Accounts payable 252 361 Price risk management liabilities 763 1,024 Other current liabilities 229 221 Total Current Liabilities 2,129 2,771 Long-term debt (excluding current portion) 1,917 1,677 Deferred income taxes 1,246 1,219 Price risk management liabilities 206 193 Accrued pension obligations 266 299 Asset retirement obligations 443 415 Other deferred credits and noncurrent liabilities 103 150 Total Noncurrent Liabilities 4,181 3,953 Total liabilities $ 6,310 $ 6,724 Adjustment for loss on spinoff 879 Net assets distributed $ 3,205 (a) The distribution of PPL Energy Supply’s cash and cash equivalents at June 1, 2015 is included in "Net cash provided by (used in) financing activities - discontinued operations" on the Statement of Cash Flows for the year ended December 31, 2015 .

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2015
Leases [Line Items]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47
LG And E And KU Energy LLC [Member]
Leases [Line Items]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47
Louisville Gas And Electric Co [Member]
Leases [Line Items]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47
Kentucky Utilities Co [Member]
Leases [Line Items]
Rent Expense for Operating Leases	Rent expense for the years ended December 31 for operating leases was as follows: 2015 2014 2013 PPL $ 49 $ 51 $ 56 LKE 24 18 18 LG&E 12 7 7 KU 11 10 10
Future Minimum Rental Payments for All Operating Leases	Total future minimum rental payments for all operating leases are estimated to be: PPL LKE LG&E KU 2016 $ 33 $ 25 $ 14 $ 10 2017 28 23 14 9 2018 24 21 13 7 2019 14 12 7 5 2020 11 9 4 5 Thereafter 31 22 10 11 Total $ 141 $ 112 $ 62 $ 47

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Annual Grant Limit Annual Grant Limit Total As % of For Individual Participants - Total Plan Outstanding Annual Grant Performance Based Awards Award PPL Common Stock Limit For awards For awards Limit On First Day of Options denominated in denominated in Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) ICP (a) 15,769,431 2% 3,000,000 SIP 10,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2% 3,000,000 (a) Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP.
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock and restricted stock units granted w as : 2015 2014 2013 PPL $ 34.50 $ 31.50 $ 30.30 PPL Electric 34.41 31.81 30.55 LKE 34.89 30.98 30.00
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock and restricted stock unit activity for 2015 was : Weighted- Average Restricted Grant Date Fair Shares/Units Value Per Share PPL Nonvested, beginning of period 3,485,520 $ 30.07 Granted 1,028,009 34.50 Anti-dilution adjustments (a) 247,098 N/A Vested (3,055,205) 29.34 Forfeited (25,947) 30.70 Nonvested, end of period (b) 1,679,475 29.65 PPL Electric Nonvested, beginning of period 286,811 $ 30.04 Transfer between registrants (22,730) 29.56 Granted 75,213 34.41 Anti-dilution adjustments (a) 18,661 N/A Vested (127,507) 29.12 Forfeited (9,363) 30.51 Nonvested, end of period 221,085 29.48 LKE Nonvested, beginning of period 341,468 $ 29.76 Transfer between registrants 4,300 31.74 Granted 98,360 34.89 Anti-dilution adjustments (a) 24,587 N/A Vested (149,752) 28.55 Nonvested, end of period 318,963 29.65 (a ) Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans. (b) Excludes 1,226,193 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was: 2015 2014 2013 PPL $ 28 $ 11 $ 12 PPL Electric 4 2 3 LKE 4 1
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2015 2014 2013 Expected stock volatility 15.90% 15.80% 15.50% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of performance units granted w as : 2015 2014 2013 PPL $ 36.76 $ 34.55 $ 34.15 PPL Electric 37.93 34.43 33.97 LKE 37.10 34.12 33.84
Performance Units, Activity Rollforward	Performance unit activity for 2015 was: Weighted- Average Grant Performance Date Fair Value Units Per Share PPL Nonvested, beginning of period 1,171,716 $ 33.77 Granted 481,197 36.76 Anti-dilution adjustment (a) 90,251 N/A Vested (509,139) 32.12 Forfeited (240,485) 33.35 Nonvested, end of period (b) 993,540 33.09 PPL Electric Nonvested, beginning of period 59,615 $ 33.77 Transfer between registrants (3,676) 35.80 Granted 21,798 37.93 Anti-dilution adjustment (a) 4,627 N/A Vested (8,497) 31.38 Forfeited (6,196) 31.38 Nonvested, end of period 67,671 33.05 LKE Nonvested, beginning of period 173,946 $ 33.32 Granted 66,439 37.10 Anti-dilution adjustment (a) 13,207 N/A Vested (30,921) 31.35 Forfeited (29,507) 31.36 Nonvested, end of period 193,164 32.96 (a) Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans. (b) Excludes 322,429 performance units for which the service vesting requirement was waived for former PPL Energy Supply employees as a result of the spinoff, but for which the ultimate number of shares to be distributed will depend on the actual attainment of the performance goals at the end of the specified perfor mance periods.
Stock Options, Valuation Assumptions	The assumptions used in the model were: 2013 Risk-free interest rate 1.15% Expected option life 6.48 years Expected stock volatility 18.50% Dividend yield 5.00%
Stock Options, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of options granted w as : 2013 PPL $ 2.18 PPL Electric 2.19 LKE 2.18
Stock Options, Activity Rollforward	Stock option activity for 2015 was: Weighted- Weighted Average Average Remaining Aggregate Number Exercise Contractual Total Intrinsic of Options Price Per Share Term (years) Value PPL Outstanding at beginning of period 9,042,962 $ 30.93 Anti-dilution adjustment (a) 907,737 28.06 Exercised (3,559,874) 27.35 Forfeited (5,676) 26.67 Outstanding at end of period 6,385,149 28.54 5.2 $ 42 Options exercisable at end of period 5,683,535 28.78 5.0 36 PPL Electric Outstanding at beginning of period 507,920 $ 30.04 Transfer between registrants (15,339) 29.60 Anti-dilution adjustment (a) 44,859 28.06 Exercised (224,007) 27.20 Outstanding at end of period 313,433 27.79 5.2 $ 2 Options exercisable at end of period 263,443 28.02 4.8 2 LKE Outstanding at beginning of period 623,317 $ 28.64 Anti-dilution adjustment (a) 43,236 28.06 Exercised (240,897) 28.04 Outstanding at end of period 425,656 26.08 6.7 $ 3 Options exercisable at end of period 277,101 25.80 6.5 2 (a) Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply .
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric a nd LKE includes an allocation of PPL Services' expense, was: 2015 2014 2013 PPL $ 33 $ 30 $ 25 PPL Electric 14 12 10 LKE 8 8 8 The income tax benefit related to above compensation expense was as follows: 2015 2014 2013 PPL $ 14 $ 12 $ 11 PPL Electric 6 5 4 LKE 3 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2015 , unrecognized compensation expense related to nonvested restricted stock, restricted stock units, performance units and stock option awards was: Weighted- Unrecognized Average Compensation Period for Expense Recognition PPL $ 8 1.6 years PPL Electric 2 1.6 years LKE 1 1.4 years
PPL Electric Utilities Corp [Member]
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Annual Grant Limit Annual Grant Limit Total As % of For Individual Participants - Total Plan Outstanding Annual Grant Performance Based Awards Award PPL Common Stock Limit For awards For awards Limit On First Day of Options denominated in denominated in Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) ICP (a) 15,769,431 2% 3,000,000 SIP 10,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2% 3,000,000 (a) Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP.
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock and restricted stock units granted w as : 2015 2014 2013 PPL $ 34.50 $ 31.50 $ 30.30 PPL Electric 34.41 31.81 30.55 LKE 34.89 30.98 30.00
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock and restricted stock unit activity for 2015 was : Weighted- Average Restricted Grant Date Fair Shares/Units Value Per Share PPL Nonvested, beginning of period 3,485,520 $ 30.07 Granted 1,028,009 34.50 Anti-dilution adjustments (a) 247,098 N/A Vested (3,055,205) 29.34 Forfeited (25,947) 30.70 Nonvested, end of period (b) 1,679,475 29.65 PPL Electric Nonvested, beginning of period 286,811 $ 30.04 Transfer between registrants (22,730) 29.56 Granted 75,213 34.41 Anti-dilution adjustments (a) 18,661 N/A Vested (127,507) 29.12 Forfeited (9,363) 30.51 Nonvested, end of period 221,085 29.48 LKE Nonvested, beginning of period 341,468 $ 29.76 Transfer between registrants 4,300 31.74 Granted 98,360 34.89 Anti-dilution adjustments (a) 24,587 N/A Vested (149,752) 28.55 Nonvested, end of period 318,963 29.65 (a ) Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans. (b) Excludes 1,226,193 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was: 2015 2014 2013 PPL $ 28 $ 11 $ 12 PPL Electric 4 2 3 LKE 4 1
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2015 2014 2013 Expected stock volatility 15.90% 15.80% 15.50% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of performance units granted w as : 2015 2014 2013 PPL $ 36.76 $ 34.55 $ 34.15 PPL Electric 37.93 34.43 33.97 LKE 37.10 34.12 33.84
Performance Units, Activity Rollforward	Performance unit activity for 2015 was: Weighted- Average Grant Performance Date Fair Value Units Per Share PPL Nonvested, beginning of period 1,171,716 $ 33.77 Granted 481,197 36.76 Anti-dilution adjustment (a) 90,251 N/A Vested (509,139) 32.12 Forfeited (240,485) 33.35 Nonvested, end of period (b) 993,540 33.09 PPL Electric Nonvested, beginning of period 59,615 $ 33.77 Transfer between registrants (3,676) 35.80 Granted 21,798 37.93 Anti-dilution adjustment (a) 4,627 N/A Vested (8,497) 31.38 Forfeited (6,196) 31.38 Nonvested, end of period 67,671 33.05 LKE Nonvested, beginning of period 173,946 $ 33.32 Granted 66,439 37.10 Anti-dilution adjustment (a) 13,207 N/A Vested (30,921) 31.35 Forfeited (29,507) 31.36 Nonvested, end of period 193,164 32.96 (a) Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans. (b) Excludes 322,429 performance units for which the service vesting requirement was waived for former PPL Energy Supply employees as a result of the spinoff, but for which the ultimate number of shares to be distributed will depend on the actual attainment of the performance goals at the end of the specified perfor mance periods.
Stock Options, Valuation Assumptions	The assumptions used in the model were: 2013 Risk-free interest rate 1.15% Expected option life 6.48 years Expected stock volatility 18.50% Dividend yield 5.00%
Stock Options, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of options granted w as : 2013 PPL $ 2.18 PPL Electric 2.19 LKE 2.18
Stock Options, Activity Rollforward	Stock option activity for 2015 was: Weighted- Weighted Average Average Remaining Aggregate Number Exercise Contractual Total Intrinsic of Options Price Per Share Term (years) Value PPL Outstanding at beginning of period 9,042,962 $ 30.93 Anti-dilution adjustment (a) 907,737 28.06 Exercised (3,559,874) 27.35 Forfeited (5,676) 26.67 Outstanding at end of period 6,385,149 28.54 5.2 $ 42 Options exercisable at end of period 5,683,535 28.78 5.0 36 PPL Electric Outstanding at beginning of period 507,920 $ 30.04 Transfer between registrants (15,339) 29.60 Anti-dilution adjustment (a) 44,859 28.06 Exercised (224,007) 27.20 Outstanding at end of period 313,433 27.79 5.2 $ 2 Options exercisable at end of period 263,443 28.02 4.8 2 LKE Outstanding at beginning of period 623,317 $ 28.64 Anti-dilution adjustment (a) 43,236 28.06 Exercised (240,897) 28.04 Outstanding at end of period 425,656 26.08 6.7 $ 3 Options exercisable at end of period 277,101 25.80 6.5 2 (a) Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply .
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric a nd LKE includes an allocation of PPL Services' expense, was: 2015 2014 2013 PPL $ 33 $ 30 $ 25 PPL Electric 14 12 10 LKE 8 8 8 The income tax benefit related to above compensation expense was as follows: 2015 2014 2013 PPL $ 14 $ 12 $ 11 PPL Electric 6 5 4 LKE 3 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2015 , unrecognized compensation expense related to nonvested restricted stock, restricted stock units, performance units and stock option awards was: Weighted- Unrecognized Average Compensation Period for Expense Recognition PPL $ 8 1.6 years PPL Electric 2 1.6 years LKE 1 1.4 years
LG And E And KU Energy LLC [Member]
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Annual Grant Limit Annual Grant Limit Total As % of For Individual Participants - Total Plan Outstanding Annual Grant Performance Based Awards Award PPL Common Stock Limit For awards For awards Limit On First Day of Options denominated in denominated in Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) ICP (a) 15,769,431 2% 3,000,000 SIP 10,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2% 3,000,000 (a) Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP.
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock and restricted stock units granted w as : 2015 2014 2013 PPL $ 34.50 $ 31.50 $ 30.30 PPL Electric 34.41 31.81 30.55 LKE 34.89 30.98 30.00
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock and restricted stock unit activity for 2015 was : Weighted- Average Restricted Grant Date Fair Shares/Units Value Per Share PPL Nonvested, beginning of period 3,485,520 $ 30.07 Granted 1,028,009 34.50 Anti-dilution adjustments (a) 247,098 N/A Vested (3,055,205) 29.34 Forfeited (25,947) 30.70 Nonvested, end of period (b) 1,679,475 29.65 PPL Electric Nonvested, beginning of period 286,811 $ 30.04 Transfer between registrants (22,730) 29.56 Granted 75,213 34.41 Anti-dilution adjustments (a) 18,661 N/A Vested (127,507) 29.12 Forfeited (9,363) 30.51 Nonvested, end of period 221,085 29.48 LKE Nonvested, beginning of period 341,468 $ 29.76 Transfer between registrants 4,300 31.74 Granted 98,360 34.89 Anti-dilution adjustments (a) 24,587 N/A Vested (149,752) 28.55 Nonvested, end of period 318,963 29.65 (a ) Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans. (b) Excludes 1,226,193 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was: 2015 2014 2013 PPL $ 28 $ 11 $ 12 PPL Electric 4 2 3 LKE 4 1
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2015 2014 2013 Expected stock volatility 15.90% 15.80% 15.50% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of performance units granted w as : 2015 2014 2013 PPL $ 36.76 $ 34.55 $ 34.15 PPL Electric 37.93 34.43 33.97 LKE 37.10 34.12 33.84
Performance Units, Activity Rollforward	Performance unit activity for 2015 was: Weighted- Average Grant Performance Date Fair Value Units Per Share PPL Nonvested, beginning of period 1,171,716 $ 33.77 Granted 481,197 36.76 Anti-dilution adjustment (a) 90,251 N/A Vested (509,139) 32.12 Forfeited (240,485) 33.35 Nonvested, end of period (b) 993,540 33.09 PPL Electric Nonvested, beginning of period 59,615 $ 33.77 Transfer between registrants (3,676) 35.80 Granted 21,798 37.93 Anti-dilution adjustment (a) 4,627 N/A Vested (8,497) 31.38 Forfeited (6,196) 31.38 Nonvested, end of period 67,671 33.05 LKE Nonvested, beginning of period 173,946 $ 33.32 Granted 66,439 37.10 Anti-dilution adjustment (a) 13,207 N/A Vested (30,921) 31.35 Forfeited (29,507) 31.36 Nonvested, end of period 193,164 32.96 (a) Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans. (b) Excludes 322,429 performance units for which the service vesting requirement was waived for former PPL Energy Supply employees as a result of the spinoff, but for which the ultimate number of shares to be distributed will depend on the actual attainment of the performance goals at the end of the specified perfor mance periods.
Stock Options, Valuation Assumptions	The assumptions used in the model were: 2013 Risk-free interest rate 1.15% Expected option life 6.48 years Expected stock volatility 18.50% Dividend yield 5.00%
Stock Options, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of options granted w as : 2013 PPL $ 2.18 PPL Electric 2.19 LKE 2.18
Stock Options, Activity Rollforward	Stock option activity for 2015 was: Weighted- Weighted Average Average Remaining Aggregate Number Exercise Contractual Total Intrinsic of Options Price Per Share Term (years) Value PPL Outstanding at beginning of period 9,042,962 $ 30.93 Anti-dilution adjustment (a) 907,737 28.06 Exercised (3,559,874) 27.35 Forfeited (5,676) 26.67 Outstanding at end of period 6,385,149 28.54 5.2 $ 42 Options exercisable at end of period 5,683,535 28.78 5.0 36 PPL Electric Outstanding at beginning of period 507,920 $ 30.04 Transfer between registrants (15,339) 29.60 Anti-dilution adjustment (a) 44,859 28.06 Exercised (224,007) 27.20 Outstanding at end of period 313,433 27.79 5.2 $ 2 Options exercisable at end of period 263,443 28.02 4.8 2 LKE Outstanding at beginning of period 623,317 $ 28.64 Anti-dilution adjustment (a) 43,236 28.06 Exercised (240,897) 28.04 Outstanding at end of period 425,656 26.08 6.7 $ 3 Options exercisable at end of period 277,101 25.80 6.5 2 (a) Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply .
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric a nd LKE includes an allocation of PPL Services' expense, was: 2015 2014 2013 PPL $ 33 $ 30 $ 25 PPL Electric 14 12 10 LKE 8 8 8 The income tax benefit related to above compensation expense was as follows: 2015 2014 2013 PPL $ 14 $ 12 $ 11 PPL Electric 6 5 4 LKE 3 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2015 , unrecognized compensation expense related to nonvested restricted stock, restricted stock units, performance units and stock option awards was: Weighted- Unrecognized Average Compensation Period for Expense Recognition PPL $ 8 1.6 years PPL Electric 2 1.6 years LKE 1 1.4 years

Retirement and Postemployment45

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	The following table provides the components of net periodic defined benefit costs for PPL's domestic (U.S.) and WPD’s (U.K.) pension and other postretirement benefit plans for the years ended December 31. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 Net periodic defined benefit costs (credits): Service cost $ 96 $ 97 $ 119 $ 79 $ 71 $ 69 $ 11 $ 12 $ 13 Interest cost 194 224 205 314 354 320 26 31 29 Expected return on plan assets (258) (287) (283) (523) (521) (465) (26) (26) (25) Amortization of: Prior service cost (credit) 7 20 22 1 1 Actuarial (gain) loss 84 28 77 158 132 150 1 6 Net periodic defined benefit costs (credits) prior to termination benefits 123 82 140 28 36 75 12 18 23 Termination benefits 13 3 Net periodic defined benefit costs (credits) $ 123 $ 95 $ 140 $ 28 $ 36 $ 78 $ 12 $ 18 $ 23 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Divestiture (a) $ (353) $ (6) Net (gain) loss 63 $ 574 $ (304) $ 508 $ 354 $ 76 (9) $ 22 $ (67) Prior service cost (credit) 18 (8) 7 Amortization of: Prior service (cost) credit (7) (20) (22) (1) (1) Actuarial gain (loss) (85) (28) (77) (158) (132) (150) (1) (6) Total recognized in OCI and regulatory assets/liabilities (b) (364) 518 (403) 350 222 (75) (16) 28 (73) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (b) $ (241) $ 613 $ (263) $ 378 $ 258 $ 3 $ (4) $ 46 $ (50) (a) As a result of the spinoff of PPL Energy Supply, amounts in AOCI were allocated to certain former active and inactive employees of PPL Energy Supply and included in the distribution . See Note 8 for additional details. (b) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. As a result, WPD does not record regulatory assets/liabilities.
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	For PPL's U.S. pension benefits and for other postretirement benefits, the amounts recog nized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 OCI $ (269) $ 319 $ (210) $ 12 $ 7 $ (37) Regulatory assets/liabilities (95) 199 (193) (28) 21 (36) Total recognized in OCI and regulatory assets/liabilities $ (364) $ 518 $ (403) $ (16) $ 28 $ (73)
Schedule of Amounts to be Amortized from AOCI and Regulatory Assets/Liabilities in Next Fiscal Year	The estimated amounts to be amortized from AOCI and regulatory assets /liabilities into net periodic defined benef it costs in 2016 are as follows: Pension Benefits U.S. U.K. Prior service cost (credit) $ 8 Actuarial (gain) loss 49 $ 151 Total $ 57 $ 151 Amortization from Balance Sheet: AOCI $ 12 $ 151 Regulatory assets/liabilities 45 Total $ 57 $ 151
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	The following n et periodic defined benefit costs (credits) were charged to operating expense or regulatory assets , excluding amounts charged to construction and other non-expense accounts. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 PPL $ 71 $ 45 $ 72 $ (21) $ (9) $ 33 $ 8 $ 10 $ 13 PPL Electric (a) 15 12 18 2 3 LKE (b) 37 17 32 8 7 8 LG&E (b) 12 5 14 4 4 4 KU (a) (b) 9 3 9 2 2 2 (a) PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. (b) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between net periodic defined benefit costs calculated in acco rdance with LKE’s, LG&E’s and KU’s pension accounting policy and the net periodic defined benefit costs calculated using a 15 year amortization period for gains and losses is recorded as a regulatory asset. Of the costs charge d to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts, $ 4 million for LG&E and $ 1 million for KU were recorded as regulatory assets.
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2015 2014 2015 2014 PPL Discount rate 4.59% 4.25% 3.68% 3.85% 4.48% 4.09% Rate of compensation increase 3.93% 3.91% 4.00% 4.00% 3.91% 3.86% LKE Discount rate 4.56% 4.25% 4.49% 4.06% Rate of compensation increase 3.50% 3.50% 3.50% 3.50% LG&E Discount rate 4.49% 4.20% The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 PPL Discount rate 4.25% 5.12% 4.22% 3.85% 4.41% 4.27% 4.09% 4.91% 4.00% Rate of compensation increase 3.91% 3.97% 3.98% 4.00% 4.00% 4.00% 3.86% 3.96% 3.97% Expected return on plan assets (a) 7.00% 7.00% 7.03% 7.19% 7.19% 7.16% 6.06% 5.96% 5.94% LKE Discount rate 4.25% 5.18% 4.24% 4.06% 4.91% 3.99% Rate of compensation increase 3.50% 4.00% 4.00% 3.50% 4.00% 4.00% Expected return on plan assets (a) 7.00% 7.00% 7.10% 6.82% 6.75% 6.76% LG&E Discount rate 4.20% 5.13% 4.20% Expected return on plan assets (a) 7.00% 7.00% 7.10% (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. The following table provides the assumed health care cost trend rates for the year s ended December 31 : 2015 2014 2013 PPL and LKE Health care cost trend rate assumed for next year - obligations 6.8% 7.2% 7.6% - cost 7.2% 7.6% 8.0% Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) - obligations 5.0% 5.0% 5.0% - cost 5.0% 5.0% 5.5% Year that the rate reaches the ultimate trend rate - obligations 2020 2020 2020 - cost 2020 2020 2019 A one percentage point change in the assumed health care costs trend rate assumption would have had the following effects on the other post retirement benefit plans in 2015 : One Percentage Point Increase Decrease Effect on accumulated postretirement benefit obligation PPL $ 6 $ (5) LKE 5 (4)
Schedule of Funded Status of Defined Benefit Plans	The funded status of PPL's plans at December 31 was as follows: Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2015 2014 2015 2014 Change in Benefit Obligation Benefit Obligation, beginning of period $ 5,399 $ 4,428 $ 8,523 $ 8,143 $ 716 $ 650 Service cost 96 97 79 71 11 12 Interest cost 194 224 314 354 26 31 Participant contributions 15 16 13 12 Plan amendments 19 (7) 6 Actuarial (gain) loss (193) 887 200 747 (37) 59 Divestiture (a) (1,416) (76) Termination benefits 13 Gross benefits paid (b) (236) (243) (391) (411) (58) (55) Federal subsidy 1 1 Currency conversion (336) (397) Benefit Obligation, end of period 3,863 5,399 8,404 8,523 596 716 Change in Plan Assets Plan assets at fair value, beginning of period 4,462 4,009 7,734 7,284 484 446 Actual return on plan assets 2 600 205 895 (2) 62 Employer contributions 158 96 366 311 17 15 Participant contributions 15 16 13 12 Divestiture (a) (1,159) (80) Gross benefits paid (b) (236) (243) (391) (411) (53) (51) Currency conversion (304) (361) Plan assets at fair value, end of period 3,227 4,462 7,625 7,734 379 484 Funded Status, end of period $ (636) $ (937) $ (779) $ (789) $ (217) $ (232) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 2 $ 1 Current liability $ (10) $ (10) $ (1) (3) (3) Noncurrent liability (626) (668) $ (779) (788) (216) (196) Noncurrent liability of discontinued operations (259) (34) Net amount recognized, end of period $ (636) $ (937) $ (779) $ (789) $ (217) $ (232) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 53 $ 41 $ 1 Net actuarial (gain) loss 977 1,353 $ 2,684 $ 2,334 37 $ 54 Total (c) $ 1,030 $ 1,394 $ 2,684 $ 2,334 $ 38 $ 54 Total accumulated benefit obligation for defined benefit pension plans $ 3,590 $ 4,946 $ 7,747 $ 7,867 (a ) As a result of the spinoff of PPL Energy Supply, obligations and assets attributable to certain former active and inactive employees of PPL Energy Supply were transferred to Talen Energy plans. ( b ) Certain U.S. pension plans offered a limited-time program in 2014 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump sum payment. G ross benefits paid i ncludes $33 million of lump-sum cash pa yments made to terminated vested participants in 2014 in connection with these offerings. (c) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and a s a result, does not record regulatory assets/lia bilities . For PPL's U.S. pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 AOCI $ 275 $ 714 $ 18 $ 30 Regulatory assets/liabilities 755 680 20 24 Total $ 1,030 $ 1,394 $ 38 $ 54
Schedule of Projected or Accumulated Benefit Obligations In Excess of Plan Assets	The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets: U.S. U.K. PBO in excess of plan assets PBO in excess of plan assets 2015 2014 2015 2014 Projected benefit obligation $ 3,863 $ 5,399 $ 8,404 $ 8,523 Fair value of plan assets 3,227 4,462 7,625 7,734 U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2015 2014 2015 2014 Accumulated benefit obligation $ 3,590 $ 4,946 $ 3,532 $ 3,592 Fair value of plan assets 3,227 4,462 3,287 3,321
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2015 Target Asset 2015 (a) 2014 Allocation (a) Growth Portfolio 51% 51% 50% Equity securities 25% 26% Debt securities (b) 13% 13% Alternative investments 13% 12% Immunizing Portfolio 47% 47% 48% Debt securities (b) 42% 44% Derivatives 5% 3% Liquidity Portfolio 2% 2% 2% Total 100% 100% 100% (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes .
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 225 $ 225 $ 246 $ 246 Equity securities: U.S.: Large-cap 87 87 114 114 Large-cap fund measured at NAV (a) 197 318 Small-cap 85 85 145 145 International equity fund at NAV (a) 454 615 Commingled debt measured at NAV (a) 514 818 Debt securities: U.S. Treasury and U.S. government sponsored agency 501 492 $ 9 723 706 $ 17 Residential/commercial backed securities 3 3 2 2 Corporate 747 737 $ 10 1,109 1,088 $ 21 International government 4 4 8 8 Other 7 7 9 9 Alternative investments: Commodities measured at NAV (a) 70 90 Real estate measured at NAV (a) 118 148 Private equity measured at NAV (a) 81 104 Hedge funds measured at NAV (a) 171 223 Derivatives: Interest rate swaps and swaptions 80 80 92 92 Other 11 11 12 12 Insurance contracts 32 32 33 33 PPL Services Corporation Master Trust assets, at fair value 3,387 $ 889 $ 851 $ 42 4,809 $ 1,211 $ 1,228 $ 54 Receivables and payables, net (b) (49) (41) 401(h) accounts restricted for other postretirement benefit obligations (111) (136) Total PPL Services Corporation Master Trust pension assets (c) $ 3,227 $ 4,632 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled alon g with interest and dividends earned but not yet received. (c) As a result of the spinoff of PPL Energy Supply, $1,159 million of assets were transferred to Talen Energy in 2015, attributable to former active and inactive employees of PPL Energy Supply that had participated in PPL’s pension plan. An additional $170 million of assets of the PPL Montana pension plan transferred to Talen Energy, as that entire plan was assumed by Talen Energy.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets cla ssified as Level 3 at December 31, 2015 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 21 $ 33 $ 54 Actual return on plan assets Relating to assets still held at the reporting date 2 2 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (10) (3) (13) Balance at end of period $ 10 $ 32 $ 42 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2014 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 23 $ 37 $ 60 Actual return on plan assets Relating to assets still held at the reporting date (1) 1 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (5) (5) Balance at end of period $ 21 $ 33 $ 54
Schedules of Target Allocation of U.S. Other Postretirement Benefit Plans VEBA Trust	The asset allocation for the PPL V EBA trusts , excluding LKE, and the target allocation, by asset class, at December 31 are detailed below. Target Asset Percentage of plan assets Allocation 2015 2014 2015 Asset Class U.S. Equity securities 48% 49% 45% Debt securities (a) 50% 49% 50% Cash and cash equivalents (b) 2% 2% 5% Total 100% 100% 100% (a) Includes commingled debt funds and debt securities. (b) Includes money market fund s .
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	The fair value of assets in the U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ 9 $ 9 U.S. Equity securities: Large-cap equity fund measure at NAV (a) 129 169 Commingled debt fund measured at NAV (a) 109 136 Debt securities: Municipalities 23 $ 23 33 $ 33 Total VEBA trust assets, at fair value 267 $ 6 $ 23 347 $ 9 $ 33 Receivables and payables, net (b) 1 1 401(h) account assets 111 136 Total other postretirement benefit plan assets (c) $ 379 $ 484 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled along wi th interest and dividends earned but not yet received. (c) As a result of the spinoff of PPL Energy Supply, $ 80 million of assets were transferred to Talen Energy in 2015, attributable to former active e mployees of PPL Energy Supply that had participated in PP L’s other postretirement benefit plan .
Schedules of Asset Allocation of U.K. Pension Plan Assets	The asset allocation and target allocation at December 31 of WPD's pension plans are detailed below. Target Asset Percentage of plan assets Allocation 2015 2014 2015 Asset Class Cash and cash equivalents 1% 1% Equity securities U.K. 3% 3% 4% European (excluding the U.K.) 2% 3% 3% Asian-Pacific 2% 2% 2% North American 3% 3% 3% Emerging markets 10% 9% 10% Currency 1% 2% 1% Global Tactical Asset Allocation 31% 29% 31% Debt securities (a) 40% 42% 39% Alternative investments 7% 6% 7% Total 100% 100% 100% (a) Includes commingled debt funds.
Schedule of Fair Value of Financial Assets for U.K. Pension Plan Assets	The fair value of assets in the U.K. pension plans by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Cash and cash equivalents $ 55 $ 55 $ 57 $ 57 Equity securities measured at NAV (a) : U.K. companies 274 239 European companies (excluding the U.K.) 190 198 Asian-Pacific companies 132 142 North American companies 220 227 Emerging markets companies 284 309 Global Equities 500 397 Currency 39 190 Other 2,384 2,263 Commingled debt: U.K. corporate bonds 2 92 U.K. gilts 3 913 Debt Securities: U.K. corporate bonds 364 $ 364 344 $ 344 U.K. gilts 2,645 2,645 1,927 1,927 Alternative investments: Real estate measured at NAV (a) 533 436 Fair value - U.K. pension plans $ 7,625 $ 55 $ 3,009 $ 7,734 $ 57 $ 2,271 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by PPL. Other Postretirement Expected Benefit Federal Pension Payment Subsidy 2016 $ 234 $ 54 $ 1 2017 245 53 1 2018 250 53 1 2019 259 53 1 2020 261 52 1 2021-2025 1,333 244 2
Schedule of Expected Cash Flows - U.K. Pension Plans - Expected Payments	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plan s. Pension 2016 $ 379 2017 384 2018 391 2019 397 2020 402 2021-2025 2,074
Expected Employer Contributions to U.S. Savings Plans	Substantially all employees of PPL's domestic subsidiaries are eligible to participate in deferred savings plans (401(k)s). Employer contributions to the plans were: 2015 2014 2013 PPL $ 34 $ 33 $ 29 PPL Electric 6 6 6 LKE 16 15 13 LG&E 5 5 7 KU 4 4 6
PPL Electric Utilities Corp [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	A llocations t o PPL Electric resulted in liabilit ies at December 31 as follows . 2015 2014 Pension $ 183 $ 212 Other postretirement benefits 67 40
LG And E And KU Energy LLC [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	The following table provides the components of net periodic defined benefit costs for LKE’s pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 Net periodic defined benefit costs (credits): Service cost $ 26 $ 21 $ 26 $ 5 $ 4 $ 5 Interest cost 68 66 62 9 9 8 Expected return on plan assets (88) (82) (82) (6) (4) (5) Amortization of: Prior service cost (credit) 7 5 5 3 2 3 Actuarial (gain) loss (a) 37 12 33 (1) Net periodic defined benefit costs (credit) $ 50 $ 22 $ 44 $ 11 $ 10 $ 11 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (gain) loss $ 20 $ 162 $ (116) $ (15) $ 26 $ (14) Prior service cost (credit) 19 23 6 Amortization of: Prior service (cost) credit (7) (5) (5) (3) (2) (3) Actuarial gain (loss) (37) (12) (33) 1 Total recognized in OCI and regulatory assets/liabilities (5) 168 (154) (18) 31 (17) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 45 $ 190 $ (110) $ (7) $ 41 $ (6) (a ) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LKE’s pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $ 9 million.
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	For LKE's pension and other postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 3 1 were as follows : Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 OCI $ 4 $ 84 $ (46) $ (2) $ 9 $ (1) Regulatory assets/liabilities (9) 84 (108) (16) 22 (16) Total recognized in OCI and regulatory assets/liabilities $ (5) $ 168 $ (154) $ (18) $ 31 $ (17)
Schedule of Amounts to be Amortized from AOCI and Regulatory Assets/Liabilities in Next Fiscal Year	The estimate d amounts to be amortized from AOCI and regulatory assets /liabilities into net periodic defined benef it costs for LKE in 2016 are as follows . Other Pension Postretirement Benefits Benefits Prior service cost (credit) $ 8 $ 2 Actuarial (gain) loss 20 Total $ 28 $ 2 Amortization from Balance Sheet: AOCI $ 2 $ 1 Regulatory assets/liabilities 26 1 Total $ 28 $ 2
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2015 2014 2015 2014 PPL Discount rate 4.59% 4.25% 3.68% 3.85% 4.48% 4.09% Rate of compensation increase 3.93% 3.91% 4.00% 4.00% 3.91% 3.86% LKE Discount rate 4.56% 4.25% 4.49% 4.06% Rate of compensation increase 3.50% 3.50% 3.50% 3.50% LG&E Discount rate 4.49% 4.20% The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 PPL Discount rate 4.25% 5.12% 4.22% 3.85% 4.41% 4.27% 4.09% 4.91% 4.00% Rate of compensation increase 3.91% 3.97% 3.98% 4.00% 4.00% 4.00% 3.86% 3.96% 3.97% Expected return on plan assets (a) 7.00% 7.00% 7.03% 7.19% 7.19% 7.16% 6.06% 5.96% 5.94% LKE Discount rate 4.25% 5.18% 4.24% 4.06% 4.91% 3.99% Rate of compensation increase 3.50% 4.00% 4.00% 3.50% 4.00% 4.00% Expected return on plan assets (a) 7.00% 7.00% 7.10% 6.82% 6.75% 6.76% LG&E Discount rate 4.20% 5.13% 4.20% Expected return on plan assets (a) 7.00% 7.00% 7.10% (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. The following table provides the assumed health care cost trend rates for the year s ended December 31 : 2015 2014 2013 PPL and LKE Health care cost trend rate assumed for next year - obligations 6.8% 7.2% 7.6% - cost 7.2% 7.6% 8.0% Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) - obligations 5.0% 5.0% 5.0% - cost 5.0% 5.0% 5.5% Year that the rate reaches the ultimate trend rate - obligations 2020 2020 2020 - cost 2020 2020 2019 A one percentage point change in the assumed health care costs trend rate assumption would have had the following effects on the other post retirement benefit plans in 2015 : One Percentage Point Increase Decrease Effect on accumulated postretirement benefit obligation PPL $ 6 $ (5) LKE 5 (4)
Schedule of Funded Status of Defined Benefit Plans	The funded status of LKE's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,608 $ 1,328 $ 234 $ 193 Service cost 26 21 5 4 Interest cost 68 66 9 9 Participant contributions 7 7 Plan amendments (a) 19 23 6 Actuarial (gain) loss (74) 253 (22) 32 Gross benefits paid (b) (59) (83) (18) (17) Federal subsidy 1 Benefit Obligation, end of period 1,588 1,608 216 234 Change in Plan Assets Plan assets at fair value, beginning of period 1,301 1,173 82 74 Actual return on plan assets (7) 173 10 Employer contributions 54 38 17 8 Participant contributions 7 7 Gross benefits paid (b) (59) (83) (18) (17) Plan assets at fair value, end of period 1,289 1,301 88 82 Funded Status, end of period $ (299) $ (307) $ (128) $ (152) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 2 $ 2 Current liability $ (3) $ (3) (3) (3) Noncurrent liability (296) (304) (127) (151) Net amount recognized, end of period $ (299) $ (307) $ (128) $ (152) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 54 $ 43 $ 9 $ 12 Net actuarial (gain) loss 338 354 (19) (4) Total $ 392 $ 397 $ (10) $ 8 Total accumulated benefit obligation for defined benefit pension plans $ 1,452 $ 1,461 (a) The pension plans were amended in December 2015 allowing terminated vested participants to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. The projected benefit obligation increased by $ 19 million as a result of the amendment. The plans were amended in December 2014 to enhance the early retirement factors for all plan participants retiring on or after January 1, 2015. These modifications resulted in an increase o f $ 23 million in the plans’ projected benefit obligations as of December 31, 2014. ( b ) Certain LKE pension plans offered a limited-time program in 2014 during which terminated vested participants could elect to receive thei r accrued pension benefit as a one-time lump-sum payment. The gross benefits paid includes $ 33 million of lump-sum cash payments made to terminated vested participants during 2014 in connection with these offerings. T he amounts recognized in AOCI and regulatory assets /liabilities at December 31 were as follows : Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 AOCI $ 70 $ 65 $ 7 $ 8 Regulatory assets/liabilities 322 332 (17) Total $ 392 $ 397 $ (10) $ 8
Schedule of Projected or Accumulated Benefit Obligations In Excess of Plan Assets	The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligations (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2015 2014 Projected benefit obligation $ 1,588 $ 1,608 Fair value of plan assets 1,289 1,301 ABO in excess of plan assets 2015 2014 Accumulated benefit obligation $ 1,452 $ 1,461 Fair value of plan assets 1,289 1,301
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2015 Target Asset 2015 (a) 2014 Allocation (a) Growth Portfolio 51% 51% 50% Equity securities 25% 26% Debt securities (b) 13% 13% Alternative investments 13% 12% Immunizing Portfolio 47% 47% 48% Debt securities (b) 42% 44% Derivatives 5% 3% Liquidity Portfolio 2% 2% 2% Total 100% 100% 100% (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes .
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 225 $ 225 $ 246 $ 246 Equity securities: U.S.: Large-cap 87 87 114 114 Large-cap fund measured at NAV (a) 197 318 Small-cap 85 85 145 145 International equity fund at NAV (a) 454 615 Commingled debt measured at NAV (a) 514 818 Debt securities: U.S. Treasury and U.S. government sponsored agency 501 492 $ 9 723 706 $ 17 Residential/commercial backed securities 3 3 2 2 Corporate 747 737 $ 10 1,109 1,088 $ 21 International government 4 4 8 8 Other 7 7 9 9 Alternative investments: Commodities measured at NAV (a) 70 90 Real estate measured at NAV (a) 118 148 Private equity measured at NAV (a) 81 104 Hedge funds measured at NAV (a) 171 223 Derivatives: Interest rate swaps and swaptions 80 80 92 92 Other 11 11 12 12 Insurance contracts 32 32 33 33 PPL Services Corporation Master Trust assets, at fair value 3,387 $ 889 $ 851 $ 42 4,809 $ 1,211 $ 1,228 $ 54 Receivables and payables, net (b) (49) (41) 401(h) accounts restricted for other postretirement benefit obligations (111) (136) Total PPL Services Corporation Master Trust pension assets (c) $ 3,227 $ 4,632 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled alon g with interest and dividends earned but not yet received. (c) As a result of the spinoff of PPL Energy Supply, $1,159 million of assets were transferred to Talen Energy in 2015, attributable to former active and inactive employees of PPL Energy Supply that had participated in PPL’s pension plan. An additional $170 million of assets of the PPL Montana pension plan transferred to Talen Energy, as that entire plan was assumed by Talen Energy.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets cla ssified as Level 3 at December 31, 2015 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 21 $ 33 $ 54 Actual return on plan assets Relating to assets still held at the reporting date 2 2 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (10) (3) (13) Balance at end of period $ 10 $ 32 $ 42 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2014 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 23 $ 37 $ 60 Actual return on plan assets Relating to assets still held at the reporting date (1) 1 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (5) (5) Balance at end of period $ 21 $ 33 $ 54
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	The fair value of assets in the U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ 9 $ 9 U.S. Equity securities: Large-cap equity fund measure at NAV (a) 129 169 Commingled debt fund measured at NAV (a) 109 136 Debt securities: Municipalities 23 $ 23 33 $ 33 Total VEBA trust assets, at fair value 267 $ 6 $ 23 347 $ 9 $ 33 Receivables and payables, net (b) 1 1 401(h) account assets 111 136 Total other postretirement benefit plan assets (c) $ 379 $ 484
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following fe deral subsidy payments are expected to be recei ved by LKE. Other Postretirement Expected Benefit Federal Pension Payment Subsidy 2016 $ 95 $ 13 2017 100 14 2018 102 15 $ 1 2019 105 16 2020 107 16 2021-2025 550 85 2
Louisville Gas And Electric Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	The following table provides the components of net periodic defined benefit costs for LG&E’s pension benefit plan for the years ended December 31. Pension Benefits 2015 2014 2013 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 $ 2 Interest cost 14 15 14 Expected return on plan assets (20) (19) (20) Amortization of: Prior service cost (credit) 3 2 2 Actuarial (gain) loss (a) 11 6 14 Net periodic defined benefit costs (credits) $ 9 $ 5 $ 12 Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: Net (gain) loss $ 8 $ 14 $ (20) Prior service cost (credit) 10 9 Amortization of: Prior service (cost) credit (3) (2) (2) Actuarial gain (loss) (11) (6) (14) Total recognized in regulatory assets/liabilities 4 15 (36) Total recognized in net periodic defined benefit costs and regulatory assets $ 13 $ 20 $ (24) (a) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E’s pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $ 3 million.
Schedule of Amounts to be Amortized from AOCI and Regulatory Assets/Liabilities in Next Fiscal Year	The estimated amounts to be amortized from regulatory assets into net periodic defined benefit costs for LG&E in 2016 are as foll ows. Pension Benefits Prior service cost (credit) $ 5 Actuarial (gain) loss 7 Total $ 12
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	In the table above LG&E amounts inc lude costs for the specific plans its sponsors and the following allocated costs of defined benefit plans sponsored by LKE , based on its participation in those plans, which management believes are reasonable : Pension Benefits Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 LG&E $ 5 $ 2 $ 5 $ 4 $ 4 $ 4
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2015 2014 2015 2014 PPL Discount rate 4.59% 4.25% 3.68% 3.85% 4.48% 4.09% Rate of compensation increase 3.93% 3.91% 4.00% 4.00% 3.91% 3.86% LKE Discount rate 4.56% 4.25% 4.49% 4.06% Rate of compensation increase 3.50% 3.50% 3.50% 3.50% LG&E Discount rate 4.49% 4.20% The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 PPL Discount rate 4.25% 5.12% 4.22% 3.85% 4.41% 4.27% 4.09% 4.91% 4.00% Rate of compensation increase 3.91% 3.97% 3.98% 4.00% 4.00% 4.00% 3.86% 3.96% 3.97% Expected return on plan assets (a) 7.00% 7.00% 7.03% 7.19% 7.19% 7.16% 6.06% 5.96% 5.94% LKE Discount rate 4.25% 5.18% 4.24% 4.06% 4.91% 3.99% Rate of compensation increase 3.50% 4.00% 4.00% 3.50% 4.00% 4.00% Expected return on plan assets (a) 7.00% 7.00% 7.10% 6.82% 6.75% 6.76% LG&E Discount rate 4.20% 5.13% 4.20% Expected return on plan assets (a) 7.00% 7.00% 7.10% (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
Schedule of Funded Status of Defined Benefit Plans	(LG&E) T he funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2015 2014 Change in Benefit Obligation Benefit Obligation, beginning of period $ 331 $ 291 Service cost 1 1 Interest cost 14 15 Plan amendments (a) 10 9 Actuarial (gain) loss (15) 36 Gross benefits paid (b) (15) (21) Benefit Obligation, end of period 326 331 Change in Plan Assets Plan assets at fair value, beginning of period 301 281 Actual return on plan assets (2) 41 Employer contributions 13 Gross benefits paid (b) (15) (21) Plan assets at fair value, end of period 297 301 Funded Status, end of period $ (29) $ (30) Amounts recognized in the Balance Sheets consist of: Noncurrent liability $ (29) $ (30) Net amount recognized, end of period $ (29) $ (30) Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost (credit) $ 29 $ 22 Net actuarial (gain) loss 95 98 Total $ 124 $ 120 Total accumulated benefit obligation for defined benefit pension plan $ 326 $ 330 ( a) The plan was amended in December 2015 allowing terminated vested participants to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. The projected benefit obligation increased by $ 10 million as a result of the amendment. The plan was amended in December 2014 to enhance the early retirement factors for all plan participants retirin g on or after January 1, 2015. Th e projected benefit obligation increased by $ 9 million as a result of the amendment. ( b ) LG&E's pension plan offered a limited-time program in 2014 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The gross benefits paid includes $ 8 million of lump-sum cash payments made to terminated vested participants in 2014 in connection with this offering. Allocations to LG&E resulted in liabilities a t December 31 as follows : 2015 2014 Pension $ 26 $ 27 Other postretirement benefits 77 85
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2015 Target Asset 2015 (a) 2014 Allocation (a) Growth Portfolio 51% 51% 50% Equity securities 25% 26% Debt securities (b) 13% 13% Alternative investments 13% 12% Immunizing Portfolio 47% 47% 48% Debt securities (b) 42% 44% Derivatives 5% 3% Liquidity Portfolio 2% 2% 2% Total 100% 100% 100% (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes .
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2015 December 31, 2014 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 225 $ 225 $ 246 $ 246 Equity securities: U.S.: Large-cap 87 87 114 114 Large-cap fund measured at NAV (a) 197 318 Small-cap 85 85 145 145 International equity fund at NAV (a) 454 615 Commingled debt measured at NAV (a) 514 818 Debt securities: U.S. Treasury and U.S. government sponsored agency 501 492 $ 9 723 706 $ 17 Residential/commercial backed securities 3 3 2 2 Corporate 747 737 $ 10 1,109 1,088 $ 21 International government 4 4 8 8 Other 7 7 9 9 Alternative investments: Commodities measured at NAV (a) 70 90 Real estate measured at NAV (a) 118 148 Private equity measured at NAV (a) 81 104 Hedge funds measured at NAV (a) 171 223 Derivatives: Interest rate swaps and swaptions 80 80 92 92 Other 11 11 12 12 Insurance contracts 32 32 33 33 PPL Services Corporation Master Trust assets, at fair value 3,387 $ 889 $ 851 $ 42 4,809 $ 1,211 $ 1,228 $ 54 Receivables and payables, net (b) (49) (41) 401(h) accounts restricted for other postretirement benefit obligations (111) (136) Total PPL Services Corporation Master Trust pension assets (c) $ 3,227 $ 4,632 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled alon g with interest and dividends earned but not yet received. (c) As a result of the spinoff of PPL Energy Supply, $1,159 million of assets were transferred to Talen Energy in 2015, attributable to former active and inactive employees of PPL Energy Supply that had participated in PPL’s pension plan. An additional $170 million of assets of the PPL Montana pension plan transferred to Talen Energy, as that entire plan was assumed by Talen Energy.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets cla ssified as Level 3 at December 31, 2015 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 21 $ 33 $ 54 Actual return on plan assets Relating to assets still held at the reporting date 2 2 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (10) (3) (13) Balance at end of period $ 10 $ 32 $ 42 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2014 is as follows : Corporate Insurance debt contracts Total Balance at beginning of period $ 23 $ 37 $ 60 Actual return on plan assets Relating to assets still held at the reporting date (1) 1 Relating to assets sold during the period (1) (1) Purchases, sales and settlements (5) (5) Balance at end of period $ 21 $ 33 $ 54
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	The following benefit pay ments, which reflect expected future service, as appropriate, are expected to be paid by the plan. Pension 2016 $ 23 2017 25 2018 24 2019 25 2020 25 2021-2025 111
Kentucky Utilities Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to KU resulted in liabilities at December 31 as follows. 2015 2014 Pension $ 46 $ 59 Other postretirement benefits 42 52

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2015
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403
LG And E And KU Energy LLC [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2015 and 2014 , the Balance Sheets reflect the owned interests in the facilities listed below. Construction Ownership Accumulated Work Interest Electric Plant Depreciation in Progress PPL and LKE December 31, 2015 Generating Plants Trimble County Unit 1 75.00% $ 399 $ 44 $ 6 Trimble County Unit 2 75.00% 1,013 141 27 December 31, 2014 Generating Plants Trimble County Unit 1 75.00% $ 309 $ 51 $ 59 Trimble County Unit 2 75.00% 1,002 122 32 LG&E December 31, 2015 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 12 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 10 $ 1 Trimble County Unit 1 75.00% 399 44 6 Trimble County Unit 2 14.25% 210 28 12 Trimble County Units 5-6 29.00% 29 6 Trimble County Units 7-10 37.00% 71 14 Cane Run Unit 7 22.00% 115 1 1 E.W. Brown Solar Unit 39.00% 4 December 31, 2014 Generating Plants E.W. Brown Units 6-7 38.00% $ 40 $ 10 Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00% 47 7 Trimble County Unit 1 75.00% 309 51 $ 59 Trimble County Unit 2 14.25% 205 23 15 Trimble County Units 5-6 29.00% 29 5 Trimble County Units 7-10 37.00% 70 11 Cane Run Unit 7 22.00% 113 KU December 31, 2015 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 19 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 43 9 $ 1 Trimble County Unit 2 60.75% 803 113 15 Trimble County Units 5-6 71.00% 70 15 Trimble County Units 7-10 63.00% 121 23 Cane Run Unit 7 78.00% 411 6 5 E.W. Brown Solar Unit 61.00% 6 December 31, 2014 Generating Plants E.W. Brown Units 6-7 62.00% $ 65 $ 15 $ 1 Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00% 42 6 Trimble County Unit 2 60.75% 797 98 17 Trimble County Units 5-6 71.00% 70 11 Trimble County Units 7-10 63.00% 120 18 1 Cane Run Unit 7 78.00% 403

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E’s gas supply operations. These contracts include the following commitments: Maximum Maturity Contract Type Date Coal 2022 Coal Transportation and Fleeting Services 2024 Natural Gas Storage 2024 Natural Gas Transportation 2026 Future obligations for power purchases from OVEC are unconditional demand payments, comprised of annual minimum debt service payments, as well as contractually required reimbursement of plant operating, maintenance and other expenses are projected as follows: LG&E KU Total 2016 $ 18 $ 8 $ 26 2017 19 8 27 2018 19 8 27 2019 19 9 28 2020 20 9 29 Thereafter 435 193 628 $ 530 $ 235 $ 765 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2015 2014 2013 LG&E $ 15 $ 17 $ 18 KU 7 8 8 Total $ 22 $ 25 $ 26
Guarantees	The table below details guarantees provided as of December 31, 2015 . Exposure at Expiration December 31, 2015 Date PPL Indemnifications related to the WPD Midlands acquisition (a) WPD indemnifications for entities in liquidation and sales of assets $ 11 (b) 2019 WPD guarantee of pension and other obligations of unconsolidated entities 114 (c) PPL Electric Guarantee of inventory value 29 (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) 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 ei ther prior o r 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. Finally, 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 ele ctric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent . At December 31, 2015 , WPD has recorded an estimated discou nted 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. T he logistics firm has title to the inventory , however, u pon termination of the contract s , 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 fall outside the cap. Another WKE-related LKE guarantee covers other indemnifications related to the p urchase 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 Oct ober 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. LKE does not believe appropriate contractual, legal or commercial grounds exist for the claim s made and has disputed the demand s . LKE believes its indemnification obligations in the WKE matter remain subject to various uncertain ties, including additional legal and contractual developments, as well as future prices, availability and demand for the subject excess power. The parties are conducting preliminary settlement discussions, however, the ultimate outcomes of the WKE termina tion-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 ou tcomes of the indemnification circumstances, but does not currently 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 sh are of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts currently included within a demand charge designed and currently expected to cover these costs over the term of the contract. LKE's proport ionate share of OVEC's outstanding debt was $ 124 million at December 31, 2015 , consisting of LG&E's share of $ 86 million and KU's share of $ 38 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" above for additional information on the OVEC power purchase contract.
LG And E And KU Energy LLC [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E’s gas supply operations. These contracts include the following commitments: Maximum Maturity Contract Type Date Coal 2022 Coal Transportation and Fleeting Services 2024 Natural Gas Storage 2024 Natural Gas Transportation 2026 Future obligations for power purchases from OVEC are unconditional demand payments, comprised of annual minimum debt service payments, as well as contractually required reimbursement of plant operating, maintenance and other expenses are projected as follows: LG&E KU Total 2016 $ 18 $ 8 $ 26 2017 19 8 27 2018 19 8 27 2019 19 9 28 2020 20 9 29 Thereafter 435 193 628 $ 530 $ 235 $ 765 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2015 2014 2013 LG&E $ 15 $ 17 $ 18 KU 7 8 8 Total $ 22 $ 25 $ 26
Louisville Gas And Electric Co [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E’s gas supply operations. These contracts include the following commitments: Maximum Maturity Contract Type Date Coal 2022 Coal Transportation and Fleeting Services 2024 Natural Gas Storage 2024 Natural Gas Transportation 2026 Future obligations for power purchases from OVEC are unconditional demand payments, comprised of annual minimum debt service payments, as well as contractually required reimbursement of plant operating, maintenance and other expenses are projected as follows: LG&E KU Total 2016 $ 18 $ 8 $ 26 2017 19 8 27 2018 19 8 27 2019 19 9 28 2020 20 9 29 Thereafter 435 193 628 $ 530 $ 235 $ 765 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2015 2014 2013 LG&E $ 15 $ 17 $ 18 KU 7 8 8 Total $ 22 $ 25 $ 26
Kentucky Utilities Co [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E’s gas supply operations. These contracts include the following commitments: Maximum Maturity Contract Type Date Coal 2022 Coal Transportation and Fleeting Services 2024 Natural Gas Storage 2024 Natural Gas Transportation 2026 Future obligations for power purchases from OVEC are unconditional demand payments, comprised of annual minimum debt service payments, as well as contractually required reimbursement of plant operating, maintenance and other expenses are projected as follows: LG&E KU Total 2016 $ 18 $ 8 $ 26 2017 19 8 27 2018 19 8 27 2019 19 9 28 2020 20 9 29 Thereafter 435 193 628 $ 530 $ 235 $ 765 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2015 2014 2013 LG&E $ 15 $ 17 $ 18 KU 7 8 8 Total $ 22 $ 25 $ 26

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2015
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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160
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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160
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 f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services , PPL EU Services and LKS charged the following amounts f or the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are beli eved to be reasonable. 2015 2014 2013 PPL Electric from PPL Services $ 125 $ 151 $ 146 LKE from PPL Services 16 15 15 PPL Electric from PPL EU Services 60 LG&E from LKS 155 140 136 KU from LKS 185 165 160

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2015
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	15. Other Income (Expense) - net (PPL) The breakdown of "Other Income (Expense) - net" for the years ended December 31 was: PPL 2015 2014 2013 Other Income Interest income $ 4 $ 1 AFUDC - equity component 14 11 $ 10 Miscellaneous 6 7 4 Total Other Income 24 19 14 Other Expense Economic foreign currency exchange contracts (Note 17) (122) (121) 38 Charitable contributions 21 27 21 Miscellaneous 17 8 10 Total Other Expense (84) (86) 69 Other Income (Expense) - net $ 108 $ 105 $ (55)

Fair Value Measurements and C50

Fair Value Measurements and Credit Concentration (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value [Line Items]
Fair Value of Assets and Liabilities Measured on Recurring Basis	The a ssets and liabilities measured at fair value were: December 31, 2015 December 31, 2014 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 836 $ 836 $ 1,399 $ 1,399 Short-term investments 120 120 Restricted cash and cash equivalents (a) 33 33 31 31 Price risk management assets (b): Foreign currency contracts 209 $ 209 130 $ 130 Cross-currency swaps 86 86 29 28 $ 1 Total price risk management assets 295 295 159 158 1 Auction rate securities (c) 2 $ 2 2 2 Total assets $ 1,166 $ 869 $ 295 $ 2 $ 1,711 $ 1,550 $ 158 $ 3 Liabilities Price risk management liabilities (b): Interest rate swaps $ 71 $ 71 $ 156 $ 156 Foreign currency contracts 1 1 2 2 Cross-currency swaps 3 3 Total price risk management liabilities $ 72 $ 72 $ 161 $ 161 PPL Electric Assets Cash and cash equivalents $ 47 $ 47 $ 214 $ 214 Restricted cash and cash equivalents (a) 2 2 3 3 Total assets $ 49 $ 49 $ 217 $ 217 LKE Assets Cash and cash equivalents $ 30 $ 30 $ 21 $ 21 Cash collateral posted to counterparties (d) 9 9 21 21 Total assets $ 39 $ 39 $ 42 $ 42 Liabilities Price risk management liabilities: Interest rate swaps $ 47 $ 47 $ 114 $ 114 Total price risk management liabilities $ 47 $ 47 $ 114 $ 114 LG&E Assets Cash and cash equivalents $ 19 $ 19 $ 10 $ 10 Cash collateral posted to counterparties (d) 9 9 21 21 Total assets $ 28 $ 28 $ 31 $ 31 Liabilities Price risk management liabilities: Interest rate swaps $ 47 $ 47 $ 81 $ 81 Total price risk management liabilities $ 47 $ 47 $ 81 $ 81 KU Assets Cash and cash equivalents $ 11 $ 11 $ 11 $ 11 Total assets $ 11 $ 11 $ 11 $ 11 Liabilities Price risk management liabilities: Interest rate swaps $ 33 $ 33 Total price risk management liabilities $ 33 $ 33 (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) Included in "Price risk management assets ", "Other current liabilities", "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (c) I ncluded in "Other current assets" on the Balance Sheets. (d) Included in "Other non current 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 of Financial Instruments Not Recorded at Fair Value - Other	The carrying amounts of long-term debt on the Balance Sheets and their estimated fair value s are set forth below , excluding long-term debt of discontinued operations at December 31, 2014. December 31, 2015 December 31, 2014 Carrying Carrying Amount Fair Value Amount Fair Value PPL $ 19,048 $ 21,218 $ 18,054 $ 20,466 PPL Electric 2,828 3,088 2,581 2,990 LKE 5,088 5,384 4,543 4,946 LG&E 1,642 1,704 1,345 1,455 KU 2,326 2,467 2,079 2,313

Derivative Instruments and He51

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table present s th e fair value and location of derivative instruments recorded on the Balance Sheets, excluding derivative instruments of discontinued operations . December 31, 2015 December 31, 2014 Derivatives designated as Derivatives not designated Derivatives designated as Derivatives not designated hedging instruments as hedging instruments hedging instruments as hedging instruments Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ 24 $ 5 $ 94 $ 5 Cross-currency swaps (b) $ 35 3 Foreign currency contracts 10 $ 94 1 $ 12 $ 67 Total current 45 24 94 6 12 97 67 5 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) 42 14 43 Cross-currency swaps (b) 51 29 Foreign currency contracts 105 5 46 2 Total noncurrent 51 105 42 34 14 46 45 Total derivatives $ 96 $ 24 $ 199 $ 48 $ 46 $ 111 $ 113 $ 50 ( a ) Included in "'Price r isk m anagement a ssets" of Current Assets, "Other current liabilities", "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheet s. (b) Excludes accrued interest, if applicable .
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities . Gain (Loss) Recognized in Income on Derivative Derivative Gain Location of Gain (Loss) Gain (Loss) Reclassified (Ineffective Portion and Derivative (Loss) Recognized in Recognized in Income from AOCI into Income Amount Excluded from Relationships OCI (Effective Portion) on Derivative (Effective Portion) Effectiveness Testing) 2015 Cash Flow Hedges: Interest rate swaps $ (34) Interest Expense $ (11) Discontinued operations $ (77) Cross-currency swaps 60 Other Income (Expense) - net 49 Interest Expense 2 Commodity contracts Discontinued operations 13 7 Total $ 26 $ 53 $ (70) Net Investment Hedges: Foreign currency contracts $ 9 2014 Cash Flow Hedges: Interest rate swaps $ (91) Interest Expense $ (18) $ 2 Cross-currency swaps 58 Other Income (Expense) - net 57 Interest Expense 4 Commodity contracts Discontinued operations 42 Total $ (33) $ 85 $ 2 Net Investment Hedges: Foreign currency contracts $ 23 2013 Cash Flow Hedges: Interest rate swaps $ 127 Interest Expense $ (20) Cross-currency swaps (41) Other Income (Expense) - net (28) Interest Expense 1 Commodity contracts Discontinued operations 210 $ 1 Total $ 86 $ 163 $ 1 Net Investment Hedges: Foreign currency contracts $ (14) Derivatives Not Designated as Location of Gain (Loss) Recognized in Hedging Instruments Income on Derivative 2015 2014 2013 Foreign currency contracts Other Income (Expense) - net $ 122 $ 121 $ (38) Interest rate swaps Interest Expense (8) (8) (8) Total $ 114 $ 113 $ (46) Derivatives Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ (22) $ (66) Regulatory liabilities - noncurrent $ 72 Derivatives Not Designated as Location of Gain (Loss) Recognized as Hedging Instruments Regulatory Liabilities/Assets 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ 1 $ (12) $ 22
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivativ e 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 Cash Cash Derivative Collateral Derivative Collateral Gross Instruments Received Net Gross Instruments Pledged Net December 31, 2015 Treasury Derivatives PPL $ 295 $ 25 $ 270 $ 72 $ 25 $ 9 $ 38 LKE 47 9 38 LG&E 47 9 38 December 31, 2014 Treasury Derivatives PPL $ 159 $ 65 $ 94 $ 161 $ 65 $ 21 $ 75 LKE 114 20 94 LG&E 81 20 61 KU 33 33
Credit Risk-Related Contingent Features	At December 31, 2015 , 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 $ 28 $ 28 $ 28 Aggregate fair value of collateral posted on these derivative instruments 9 9 9 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 19 19 19 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.
LG And E And KU Energy LLC [Member]
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges. December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 66 (a) Represents the location on the Balance Sheet. The following table present s th e fair value and the location on the Balance Sheets of derivative s not designated as hedging instruments . December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 5 $ 5 Total current 5 5 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps 42 43 Total noncurrent 42 43 Total derivatives $ 47 $ 48 (a) Represents the location on the Balance Sheet s .
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following table present s the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets and liabilities . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ (22) $ (66) Regulatory liabilities - noncurrent $ 72 The following table s present the pre-tax effect of derivative s not designated as cash flow hedges that are recognized in income or regulatory assets . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Interest Expense $ (8) $ (8) $ (8) Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ 1 $ (12) $ 22
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivativ e 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 Cash Cash Derivative Collateral Derivative Collateral Gross Instruments Received Net Gross Instruments Pledged Net December 31, 2015 Treasury Derivatives PPL $ 295 $ 25 $ 270 $ 72 $ 25 $ 9 $ 38 LKE 47 9 38 LG&E 47 9 38 December 31, 2014 Treasury Derivatives PPL $ 159 $ 65 $ 94 $ 161 $ 65 $ 21 $ 75 LKE 114 20 94 LG&E 81 20 61 KU 33 33
Credit Risk-Related Contingent Features	At December 31, 2015 , 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 $ 28 $ 28 $ 28 Aggregate fair value of collateral posted on these derivative instruments 9 9 9 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 19 19 19 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.
Louisville Gas And Electric Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges. December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 33 (a) Represents the location on the balance sheet. The following table present s th e fair value and the location on the Balance Sheets of derivative s not designated as hedging instruments . December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 5 $ 5 Total current 5 5 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps 42 43 Total noncurrent 42 43 Total derivatives $ 47 $ 48 (a) Represents the location on the Balance Sheet s .
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following table present s the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets and liabilities . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory asset - noncurrent $ (11) $ (33) Regulatory liabilities - noncurrent $ 36 The following table s present the pre-tax effect of derivative s not designated as cash flow hedges that are recognized in income or regulatory assets . Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Interest Expense $ (8) $ (8) $ (8) Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ 1 $ (12) $ 22
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivativ e 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 Cash Cash Derivative Collateral Derivative Collateral Gross Instruments Received Net Gross Instruments Pledged Net December 31, 2015 Treasury Derivatives PPL $ 295 $ 25 $ 270 $ 72 $ 25 $ 9 $ 38 LKE 47 9 38 LG&E 47 9 38 December 31, 2014 Treasury Derivatives PPL $ 159 $ 65 $ 94 $ 161 $ 65 $ 21 $ 75 LKE 114 20 94 LG&E 81 20 61 KU 33 33
Credit Risk-Related Contingent Features	At December 31, 2015 , 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 $ 28 $ 28 $ 28 Aggregate fair value of collateral posted on these derivative instruments 9 9 9 Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 19 19 19 (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]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges . December 31, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ 33 (a) Represents the location on the Balance S heet s
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	Derivative Instruments Location of Gain (Loss) 2015 2014 2013 Interest rate swaps Regulatory assets - noncurrent $ (11) $ (33) Regulatory liabilities - noncurrent $ 36
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivativ e 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 Cash Cash Derivative Collateral Derivative Collateral Gross Instruments Received Net Gross Instruments Pledged Net December 31, 2015 Treasury Derivatives PPL $ 295 $ 25 $ 270 $ 72 $ 25 $ 9 $ 38 LKE 47 9 38 LG&E 47 9 38 December 31, 2014 Treasury Derivatives PPL $ 159 $ 65 $ 94 $ 161 $ 65 $ 21 $ 75 LKE 114 20 94 LG&E 81 20 61 KU 33 33

Goodwill and Other Intangible52

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Goodwill and Other Intangible Assets [Line Items]
Goodwill Rollforward	18. Goodwill and Other Intangible Assets Goodwill (PPL) The changes in the carrying amount of goodwill by segment were: U.K. Regulated Kentucky Regulated Total 2015 2014 2015 2014 2015 2014 Balance at beginning of period (a) $ 3,005 $ 3,143 $ 662 $ 662 $ 3,667 $ 3,805 Effect of foreign currency exchange rates (117) (138) (117) (138) Balance at end of period (a) $ 2,888 $ 3,005 $ 662 $ 662 $ 3,550 $ 3,667 (a ) There were no accumulated impairment losses related to goodwill.
Other Intangible Assets	Other Intangible Assets (PPL) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Contracts (a) $ 407 $ 300 $ 408 $ 250 Land and transmission rights 337 111 329 108 Emission allowances/RECs (b) 5 5 Licenses and other 10 5 10 5 Total subject to amortization 759 416 752 363 Not subject to amortization due to indefinite life: Land and transmission rights 33 29 Easements (c) 303 250 Total not subject to amortization due to indefinite life 336 279 Total $ 1,095 $ 416 $ 1,031 $ 363 (a) Gross carrying amount includes the fair value at the acquisition date of the OVEC power purchase contract and coal contracts with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL. Offsetting regulatory liabilities were recorded related to these contracts, which are being amortized over the same period as the intangible assets, eliminating any income statement impact. This is referred to as "regulatory offset" in the tables below. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization. (c) Primarily from an increase in easements at WPD.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization Expense was as follows: 2015 2014 2013 Intangible assets with no regulatory offset $ 6 $ 6 $ 6 Intangible assets with regulatory offset 51 47 51 Total $ 57 $ 53 $ 57
Future Amortization Expense	Amortization expense for each of the next five years, excluding insignificant amounts for consumption of emission allowances/RECs, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with no regulatory offset $ 6 $ 6 $ 6 $ 6 $ 6 Intangible assets with regulatory offset 27 9 9 9 8 Total $ 33 $ 15 $ 15 $ 15 $ 14
PPL Electric Utilities Corp [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	(PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Land and transmission rights $ 316 $ 108 $ 308 $ 105 Licenses and other 4 1 4 1 Total subject to amortization 320 109 312 106 Not subject to amortization due to indefinite life: Land and transmission rights 33 29 Total $ 353 $ 109 $ 341 $ 106
LG And E And KU Energy LLC [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	(LKE) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Coal contracts (a) $ 269 $ 252 $ 269 $ 210 Land and transmission rights 21 2 21 2 Emission allowances (b) 3 3 OVEC power purchase agreement (c) 126 42 126 33 Total subject to amortization $ 419 $ 296 $ 419 $ 245 (a) Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL . An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization. (c) Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional inf ormation.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2015 2014 2013 Intangible assets with no regulatory offset $ 1 Intangible assets with regulatory offset $ 51 $ 47 51 Total $ 51 $ 47 $ 52
Future Amortization Expense	Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with regulatory offset $ 27 $ 9 $ 9 $ 9 $ 8
Louisville Gas And Electric Co [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	(LG&E) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Coal contracts (a) $ 124 $ 116 $ 124 $ 98 Land and transmission rights 7 1 7 1 Emission allowances (b) 1 1 OVEC power purchase agreement (c) 87 29 87 23 Total subject to amortization $ 219 $ 146 $ 219 $ 122 (a) Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there i s no accumulated amortization. (c) Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL . An offsetting regulatory liability was reco rded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2015 2014 2013 Intangible assets with regulatory offset $ 24 $ 23 $ 23
Future Amortization Expense	Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with regulatory offset $ 14 $ 6 $ 6 $ 6 $ 6
Kentucky Utilities Co [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	(KU) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2015 December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Amount Amortization Subject to amortization: Coal contracts (a) $ 145 $ 136 $ 145 $ 112 Land and transmission rights 14 1 14 1 Emission allowances (b) 2 2 OVEC power purchase agreement (c) 39 13 39 10 Total subject to amortization $ 200 $ 150 $ 200 $ 123 (a) Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information. (b) Emission allowances/RECs are expensed when consumed or sold; therefore, there i s no accumulated amortization. (c) Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was r ecorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2015 2014 2013 Intangible assets with no regulatory offset $ 1 Intangible assets with regulatory offset $ 27 $ 24 28 Total $ 27 $ 24 $ 29
Future Amortization Expense	Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be: 2016 2017 2018 2019 2020 Intangible assets with regulatory offset $ 13 $ 3 $ 3 $ 3 $ 2

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carryin g amounts of AROs were as follows. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 ARO at beginning of period $ 336 $ 301 $ 285 $ 252 $ 74 $ 74 $ 211 $ 178 Accretion 19 16 18 14 5 4 13 10 Obligations incurred 5 1 5 1 3 2 1 Changes in estimated cash flow or settlement date 235 25 234 23 98 1 136 22 Effect of foreign currency exchange rates (2) (2) Obligations settled (7) (5) (7) (5) (5) (5) (2) ARO at end of period $ 586 $ 336 $ 535 $ 285 $ 175 $ 74 $ 360 $ 211
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carryin g amounts of AROs were as follows. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 ARO at beginning of period $ 336 $ 301 $ 285 $ 252 $ 74 $ 74 $ 211 $ 178 Accretion 19 16 18 14 5 4 13 10 Obligations incurred 5 1 5 1 3 2 1 Changes in estimated cash flow or settlement date 235 25 234 23 98 1 136 22 Effect of foreign currency exchange rates (2) (2) Obligations settled (7) (5) (7) (5) (5) (5) (2) ARO at end of period $ 586 $ 336 $ 535 $ 285 $ 175 $ 74 $ 360 $ 211
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carryin g amounts of AROs were as follows. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 ARO at beginning of period $ 336 $ 301 $ 285 $ 252 $ 74 $ 74 $ 211 $ 178 Accretion 19 16 18 14 5 4 13 10 Obligations incurred 5 1 5 1 3 2 1 Changes in estimated cash flow or settlement date 235 25 234 23 98 1 136 22 Effect of foreign currency exchange rates (2) (2) Obligations settled (7) (5) (7) (5) (5) (5) (2) ARO at end of period $ 586 $ 336 $ 535 $ 285 $ 175 $ 74 $ 360 $ 211
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carryin g amounts of AROs were as follows. PPL LKE LG&E KU 2015 2014 2015 2014 2015 2014 2015 2014 ARO at beginning of period $ 336 $ 301 $ 285 $ 252 $ 74 $ 74 $ 211 $ 178 Accretion 19 16 18 14 5 4 13 10 Obligations incurred 5 1 5 1 3 2 1 Changes in estimated cash flow or settlement date 235 25 234 23 98 1 136 22 Effect of foreign currency exchange rates (2) (2) Obligations settled (7) (5) (7) (5) (5) (5) (2) ARO at end of period $ 586 $ 336 $ 535 $ 285 $ 175 $ 74 $ 360 $ 211

Accumulated Other Comprehensi54

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the years ended December 31 were as follows. Unrealized gains (losses) Defined benefit plans Foreign currency Available- Equity Prior Actuarial translation for-sale Qualifying investees' service gain adjustments securities derivatives AOCI costs (loss) Total PPL December 31, 2012 $ (149) $ 111 $ 132 $ 1 $ (14) $ (2,021) $ (1,940) Amounts arising during the year 138 67 45 2 71 323 Reclassifications from AOCI (6) (83) 6 135 52 Net OCI during the year 138 61 (38) 8 206 375 December 31, 2013 $ (11) $ 172 $ 94 $ 1 $ (6) $ (1,815) $ (1,565) Amounts arising during the year (275) 35 (10) 5 (509) (754) Reclassifications from AOCI (6) (64) 4 111 45 Net OCI during the year (275) 29 (74) 9 (398) (709) December 31, 2014 $ (286) $ 201 $ 20 $ 1 $ 3 $ (2,213) $ (2,274) Amounts arising during the year (234) 8 26 (9) (366) (575) Reclassifications from AOCI (2) 2 (1) 146 145 Net OCI during the year (234) 6 28 (1) (9) (220) (430) Distribution of PPL Energy Supply (See Note 8) (207) (55) 238 (24) December 31, 2015 $ (520) $ $ (7) $ $ (6) $ (2,195) $ (2,728) LKE December 31, 2012 $ 1 $ (2) $ (14) $ (15) Amounts arising during the year 28 28 Net OCI during the year 28 28 December 31, 2013 $ 1 $ (2) $ 14 $ 13 Amounts arising during the year (7) (50) (57) Reclassifications from AOCI (1) 1 (1) (1) Net OCI during the year (1) (6) (51) (58) December 31, 2014 $ $ (8) $ (37) $ (45) Amounts arising during the year (3) (4) (7) Reclassifications from AOCI 1 5 6 Net OCI during the year (2) 1 (1) December 31, 2015 $ $ (10) $ (36) $ (46)
Reclassification out of Other Comprehensive Income (Loss)	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2015 and 2014 . PPL Affected Line Item on the Details about AOCI 2015 2014 Statements of Income Available-for-sale securities $ 4 $ 13 Other Income (Expense) - net Total Pre-tax 4 13 Income Taxes (2) (7) Total After-tax 2 6 Qualifying derivatives Interest rate swaps (11) (16) Interest Expense (77) Discontinued operations Cross-currency swaps 49 57 Other Income (Expense) - net 2 4 Interest Expense Commodity contracts 20 42 Discontinued operations Total Pre-tax (17) 87 Income Taxes 15 (23) Total After-tax (2) 64 Equity Investees' AOCI 1 Other Income (Expense) - net Total Pre-tax 1 Income Taxes Total After-tax 1 Defined benefit plans Prior service costs (7) Net actuarial loss (192) (145) Total Pre-tax (192) (152) Income Taxes 46 37 Total After-tax (146) (115) Total reclassifications during the year $ (145) $ (45)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the years ended December 31 were as follows. Unrealized gains (losses) Defined benefit plans Foreign currency Available- Equity Prior Actuarial translation for-sale Qualifying investees' service gain adjustments securities derivatives AOCI costs (loss) Total PPL December 31, 2012 $ (149) $ 111 $ 132 $ 1 $ (14) $ (2,021) $ (1,940) Amounts arising during the year 138 67 45 2 71 323 Reclassifications from AOCI (6) (83) 6 135 52 Net OCI during the year 138 61 (38) 8 206 375 December 31, 2013 $ (11) $ 172 $ 94 $ 1 $ (6) $ (1,815) $ (1,565) Amounts arising during the year (275) 35 (10) 5 (509) (754) Reclassifications from AOCI (6) (64) 4 111 45 Net OCI during the year (275) 29 (74) 9 (398) (709) December 31, 2014 $ (286) $ 201 $ 20 $ 1 $ 3 $ (2,213) $ (2,274) Amounts arising during the year (234) 8 26 (9) (366) (575) Reclassifications from AOCI (2) 2 (1) 146 145 Net OCI during the year (234) 6 28 (1) (9) (220) (430) Distribution of PPL Energy Supply (See Note 8) (207) (55) 238 (24) December 31, 2015 $ (520) $ $ (7) $ $ (6) $ (2,195) $ (2,728) LKE December 31, 2012 $ 1 $ (2) $ (14) $ (15) Amounts arising during the year 28 28 Net OCI during the year 28 28 December 31, 2013 $ 1 $ (2) $ 14 $ 13 Amounts arising during the year (7) (50) (57) Reclassifications from AOCI (1) 1 (1) (1) Net OCI during the year (1) (6) (51) (58) December 31, 2014 $ $ (8) $ (37) $ (45) Amounts arising during the year (3) (4) (7) Reclassifications from AOCI 1 5 6 Net OCI during the year (2) 1 (1) December 31, 2015 $ $ (10) $ (36) $ (46)

Quarterly Financial Information

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL, COMMON STOCK PRICE AND DIVIDEND DATA (Unaudited) PPL Corporation and Subsidiaries (Millions of Dollars, except per share data) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2015 Operating revenues $ 2,230 $ 1,781 $ 1,878 $ 1,780 Operating income 890 638 686 617 Income from continuing operations after income taxes 552 250 396 405 Income (loss) from discontinued operations (net of income taxes) (d)(e) 95 (1,007) (3) (6) Net income (loss) (e) 647 (757) 393 399 Income from continuing operations after income taxes available to PPL common shareowners: (b) Basic EPS 0.83 0.37 0.59 0.60 Diluted EPS 0.82 0.37 0.59 0.60 Net income (loss) available to PPL common shareowners: (b) Basic EPS 0.97 (1.13) 0.58 0.59 Diluted EPS 0.96 (1.13) 0.58 0.59 Dividends declared per share of common stock (c) 0.3725 0.3725 0.3775 0.3775 Price per common share: High $ 36.38 $ 34.85 $ 33.58 $ 34.75 Low 31.40 29.45 29.41 32.60 2014 Operating revenues $ 2,178 $ 1,849 $ 1,879 $ 1,946 Operating income 801 678 688 700 Income from continuing operations after income taxes 389 230 410 408 Income (loss) from discontinued operations (net of income taxes) (d)(f) (73) (1) 87 287 Net income (f) 316 229 497 695 Income from continuing operations after income taxes available to PPL common shareowners: (b) Basic EPS 0.61 0.35 0.61 0.62 Diluted EPS 0.61 0.34 0.61 0.62 Net income available to PPL common shareowners: (b) Basic EPS 0.50 0.35 0.74 1.04 Diluted EPS 0.49 0.34 0.74 1.04 Dividends declared per share of common stock (c) 0.3725 0.3725 0.3725 0.3725 Price per common share: High $ 33.24 $ 35.56 $ 35.52 $ 38.14 Low 29.40 32.32 31.79 32.09 (a) Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations. ( b ) The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding. (c ) PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future d ividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors. (d ) In the second quarter of 2015, PPL completed the spinoff of PPL Energy Supply sub stantially representing PPL's Supply segment. Accordingly, the previously reported operating results for PPL’s Supply segment have been reclassified as discontinued operations. See Note 8 to the Financial Statements for additional information. (e) The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information. (f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL DATA (Unaudited) PPL Electric Utilities Corporation and Subsidiaries (Millions of Dollars) For the Quarters Ended (a) March 31 June 30 Sept. 30 Dec. 31 2015 Operating revenues $ 630 $ 476 $ 519 $ 499 Operating income 175 116 121 126 Net income 87 49 55 61 2014 Operating revenues $ 592 $ 449 $ 477 $ 526 Operating income 165 111 124 138 Net income 85 52 57 69 (a) PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

Summary of Significant Accoun56

Summary of Significant Accounting Policies (Details) $ / shares in Units, $ in Millions		3 Months Ended																12 Months Ended
		Dec. 31, 2015USD ($)		Sep. 30, 2015USD ($)		Jun. 30, 2015USD ($)		Mar. 31, 2015USD ($)		Dec. 31, 2014USD ($)		Sep. 30, 2014USD ($)		Jun. 30, 2014USD ($)		Mar. 31, 2014USD ($)		Dec. 31, 2015GBP (£)IntegerMW	Dec. 31, 2015USD ($)Integer$ / sharesMW	Dec. 31, 2014USD ($)		Dec. 31, 2013USD ($)
Utility Revenue (Details) [Abstract]
Domestic electric and gas revenue	[1]																		$ 5,239	$ 5,209		$ 4,842
U.K. electric revenue	[2]																		2,410	2,621		2,403
Domestic - other																			20	22		18
Operating Revenues		$ 1,780	[3]	$ 1,878	[3]	$ 1,781	[3]	$ 2,230	[3]	$ 1,946	[3]	$ 1,879	[3]	$ 1,849	[3]	$ 2,178	[3]		7,669	7,852		7,263
Restricted Cash and Cash Equivalents (Numeric) [Abstract]
Restricted cash and cash equivalents		$ 33								31									33	31
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period																			$ 11	16		15
Defined Benefits [Abstract]
Difference between the actual value of plan assets and the expected value		20.00%																	20.00%
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization																		30.00%	30.00%
The expected average remaining service of active plan participants																		50.00%	50.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis																		10.00%	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis																		30.00%	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized																		50.00%	50.00%
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		$ 357								381									$ 357	381
New Accounting Pronouncement Early Adoption [Member]
Balance Sheet Classification of Deferred Taxes [Abstract]
Assets										125										125
Liabilities										0										0
Discontinued Operations - Assets										8										8
Discontinued Operations - Liabilities										4										4
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		168								166									168	166
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	[4]	42								54									42	54
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		147								161									$ 147	$ 161
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates																		2.57%	2.57%	2.92%
Low Carbon Network Fund [Member]
Restricted Cash and Cash Equivalents (Numeric) [Abstract]
Restricted cash and cash equivalents	[5]	22								19									$ 22	$ 19
Other Restricted Cash [Member]
Restricted Cash and Cash Equivalents (Numeric) [Abstract]
Restricted cash and cash equivalents		11								12									11	12
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period								44								43			44	43		41
Additions charged to income																			49	49		38
Additions charged to other accounts																			(2)	0		4	[6]
Deductions	[7]																		50	48		40
Balance at end of period		41								44									41	44		43
Unaffiliated Third Party Entity [Member]
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable																			$ 1,300	$ 1,100		985
WPD [Member]
Summary of Significant Accounting Policies [Line Items]
Period of lag in reporting results for WPD (in months) | Integer																		1	1
Revenue Recognition (Numeric) [Abstract]
Number of regulatory years later future demand revenue is affected																		2 years	2 years
Projected reduction to base demand revenue from a true up of forecasted RPI (projected TRU) for the 2015/16 regulatory year																			$ 45
Projected reduction to base demand revenue from a true up of forecasted RPI (projected TRU) in calendar year 2017																			30
Projected reduction to base demand revenue from a true up of forecasted RPI (projected TRU) in calendar year 2018																			$ 15
Percentage WPD's distribution network operators are able to retain of any under-spends																		70.00%	70.00%
Percentage WPD's distribution network operators bear of any over-spends																		70.00%	70.00%
Trailing average period used in the cost of debt calculation																		10 years	10 years
Projected reduction to revenue from a difference in prior periods between actual values and those in the agreed business plan (projected MOD adjustment) for the 2015/16 regulatory year																			$ 11
Projected reduction to revenue from a difference in prior periods between actual values and those in the agreed business plan (projected MOD adjustment) in calendar year 2017																			5
Projected reduction to revenue from a difference in prior periods between actual values and those in the agreed business plan (projected MOD adjustment) in calendar year 2018																			$ 6
Refunded/recovered period of lag for recovery of over and under-recovered amounts arising from 2014/15 onwards																		2 years	2 years
Previous refunded/recovered period of lag for recovery of over and under-recovered amounts																		1 year	1 year
Amount per residential network customer reduction given through reduced tariffs to be recovered | £																		£ 5
Amount of total recovery from residential network customer reduction given through reduced tariffs																			$ 56
WPD [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted average useful life																		69 years	69 years	55 years
Decrease in depreciation expense from change in weighted average useful lives																			$ 84
Decrease in depreciation expense from change in weighted average useful lives, after-tax																			$ 66
Decrease in depreciation expense from change in weighted average useful lives, per share | $ / shares																			$ 0.1
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues		499	[8]	$ 519	[8]	$ 476	[8]	630	[8]	526	[8]	$ 477	[8]	$ 449	[8]	592	[8]		$ 2,124	$ 2,044		1,870
Restricted Cash and Cash Equivalents (Numeric) [Abstract]
Restricted cash and cash equivalents		$ 2								3									$ 2	3
Defined Benefits [Abstract]
Difference between the actual value of plan assets and the expected value		20.00%																	20.00%
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization																		30.00%	30.00%
The expected average remaining service of active plan participants																		50.00%	50.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis																		10.00%	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis																		30.00%	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized																		50.00%	50.00%
Intercompany tax receivables (payables)		$ 56								(25)									$ 56	(25)
PPL Electric Utilities Corp [Member] | New Accounting Pronouncement Early Adoption [Member]
Balance Sheet Classification of Deferred Taxes [Abstract]
Assets										58										58
Liabilities										0										$ 0
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates																		2.46%	2.46%	2.46%
PPL Electric Utilities Corp [Member] | Other Restricted Cash [Member]
Restricted Cash and Cash Equivalents (Numeric) [Abstract]
Restricted cash and cash equivalents		2								3									$ 2	$ 3
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period								17								18			17	18		18
Additions charged to income																			39	34		32
Deductions	[7]																		40	35		32
Balance at end of period		$ 16								17									16	17		18
PPL Electric Utilities Corp [Member] | Unaffiliated Third Party Entity [Member]
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable																			1,300	1,100		985
PPL Electric Utilities Corp [Member] | PPL EnergyPlus [Member]
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable																			146	336		294
LG And E And KU Energy LLC [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues																			$ 3,115	3,168		2,976
Defined Benefits [Abstract]
Difference between the actual value of plan assets and the expected value		20.00%																	20.00%
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization																		30.00%	30.00%
The expected average remaining service of active plan participants																		50.00%	50.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis																		10.00%	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis																		30.00%	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized																		50.00%	50.00%
Intercompany tax receivables (payables)		$ (10)								136									$ (10)	136
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		298								311									298	311
LG And E And KU Energy LLC [Member] | New Accounting Pronouncement Early Adoption [Member]
Balance Sheet Classification of Deferred Taxes [Abstract]
Assets										16										16
Liabilities										0										0
LG And E And KU Energy LLC [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		168								166									168	166
LG And E And KU Energy LLC [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	[4]	42								54									42	54
LG And E And KU Energy LLC [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		88								91									$ 88	$ 91
LG And E And KU Energy LLC [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates																		3.69%	3.69%	3.80%
LG And E And KU Energy LLC [Member] | Ohio Valley Electric Corporation [Member]
Cost Method Investments [Abstract]
Number of electric utilities that are equity owners | Integer																		10	10
Number of companies power is supplied to | Integer																		11	11
LG And E And KU Energy LLC [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period								25								22			$ 25	$ 22		19
Additions charged to income																			9	14		4
Additions charged to other accounts																			(2)	0		4	[6]
Deductions	[7]																		9	11		5
Balance at end of period		$ 23								25									$ 23	25		22
LG And E And KU Energy LLC [Member] | LGE [Member] | Ohio Valley Electric Corporation [Member]
Cost Method Investments [Abstract]
Ownership percentage																		5.63%	5.63%
Generation capacity in terms of ownership percentage (in MW) | MW																		120	120
LG And E And KU Energy LLC [Member] | KU [Member] | Ohio Valley Electric Corporation [Member]
Cost Method Investments [Abstract]
Ownership percentage																		2.50%	2.50%
Generation capacity in terms of ownership percentage (in MW) | MW																		53	53
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues																			$ 1,444	1,533		1,410
Defined Benefits [Abstract]
Difference between the actual value of plan assets and the expected value		20.00%																	20.00%
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization																		30.00%	30.00%
The expected average remaining service of active plan participants																		50.00%	50.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis																		10.00%	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis																		30.00%	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized																		50.00%	50.00%
Intercompany tax receivables (payables)		$ 4								74									$ 4	74
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		151								162									151	162
Louisville Gas And Electric Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		71								66									71	66
Louisville Gas And Electric Co [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	[4]	42								54									42	54
Louisville Gas And Electric Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		38								42									$ 38	$ 42
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates																		3.65%	3.65%	4.05%
Louisville Gas And Electric Co [Member] | Ohio Valley Electric Corporation [Member]
Cost Method Investments [Abstract]
Number of electric utilities that are equity owners | Integer																		10	10
Number of companies power is supplied to | Integer																		11	11
Ownership percentage																		5.63%	5.63%
Generation capacity in terms of ownership percentage (in MW) | MW																		120	120
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period								2								2			$ 2	$ 2		1
Additions charged to income																			2	5		2
Additions charged to other accounts																			0	(1)	[6]	1	[6]
Deductions	[7]																		3	4		2
Balance at end of period		$ 1								2									1	2		2
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues																			$ 1,728	1,737		1,635
Defined Benefits [Abstract]
Difference between the actual value of plan assets and the expected value		20.00%																	20.00%
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization																		30.00%	30.00%
The expected average remaining service of active plan participants																		50.00%	50.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis																		10.00%	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis																		30.00%	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized																		50.00%	50.00%
Intercompany tax receivables (payables)		$ (5)								60									$ (5)	60
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		147								149									147	149
Kentucky Utilities Co [Member] | New Accounting Pronouncement Early Adoption [Member]
Balance Sheet Classification of Deferred Taxes [Abstract]
Assets										2										2
Liabilities										0										0
Kentucky Utilities Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		97								100									97	100
Kentucky Utilities Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet		50								49									$ 50	$ 49
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates																		3.71%	3.71%	3.63%
Kentucky Utilities Co [Member] | Ohio Valley Electric Corporation [Member]
Cost Method Investments [Abstract]
Number of electric utilities that are equity owners | Integer																		10	10
Number of companies power is supplied to | Integer																		11	11
Ownership percentage																		2.50%	2.50%
Generation capacity in terms of ownership percentage (in MW) | MW																		53	53
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period								$ 2								$ 4			$ 2	$ 4		2
Additions charged to income																			5	8		3
Additions charged to other accounts																			0	(3)	[6]	3	[6]
Deductions	[7]																		5	7		4
Balance at end of period		$ 2								$ 2									$ 2	$ 2		$ 4
[1]	Represents revenues from cost-based rate-regulated generation, transmission and/or distribution in Pennsylvania, Kentucky, Virginia and Tennessee, includ ing regulated wholesale revenue.
[2]	Primarily represents regulated electricity distribution revenues from the operation of WPD's distribution networks.
[3]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.
[4]	The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers .
[5]	Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
[6]	Primarily related to capital projects, thus the provision was recorded as an adjustment to construction work in progress .
[7]	Primarily related to uncollectible accounts written off.
[8]	PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

Segment and Related Informati57

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) $ in Millions		3 Months Ended																12 Months Ended
		Dec. 31, 2015USD ($)		Sep. 30, 2015USD ($)		Jun. 30, 2015USD ($)		Mar. 31, 2015USD ($)		Dec. 31, 2014USD ($)		Sep. 30, 2014USD ($)		Jun. 30, 2014USD ($)		Mar. 31, 2014USD ($)		Dec. 31, 2015USD ($)Integer		Dec. 31, 2014USD ($)		Dec. 31, 2013USD ($)
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer																		3
Income Statement Data
Revenues		$ 1,780	[1]	$ 1,878	[1]	$ 1,781	[1]	$ 2,230	[1]	$ 1,946	[1]	$ 1,879	[1]	$ 1,849	[1]	$ 2,178	[1]	$ 7,669		$ 7,852		$ 7,263
Depreciation																		883		923		843
Amortization																		59		65		66
Unrealized (gains) losses on derivatives, and other hedging activities																		(77)		(187)		56
Interest Expenses																		871		843		778
Income from Continuing Operations Before Income Taxes																		2,068		2,129		1,728
Income Taxes																		465		692		360
Deferred income taxes and investment tax credits	[2]																	428		666		387
Net income		399	[1]	393	[1]	(757)	[1],[3]	647	[1]	695	[1],[4]	497	[1]	229	[1]	316	[1]	682		1,737		1,130
Cash Flow [Abstract]
Expenditures for long-lived assets																		3,570		3,723		3,682
Balance Sheet Data
Assets		39,301								48,606								39,301		48,606
Kentucky Regulated [Member]
Income Statement Data
Revenues	[5]																	3,115		3,168		2,976
Depreciation																		382		354		334
Amortization	[6]																	27		25		22
Unrealized (gains) losses on derivatives, and other hedging activities	[7]																	11		12		12
Interest Expenses																		232		219		212
Income from Continuing Operations Before Income Taxes																		547		501		484
Income Taxes	[8]																	221		189		179
Deferred income taxes and investment tax credits	[2]																	236		449		254
Net income																		326		312		307
Cash Flow [Abstract]
Expenditures for long-lived assets																		1,210		1,262		1,434
Balance Sheet Data
Assets		13,756								13,022								13,756		13,022
United Kingdom Regulated [Member]
Income Statement Data
Revenues	[5]																	2,410		2,621		2,403
Depreciation																		242		337		300
Amortization	[6]																	6		17		19
Unrealized (gains) losses on derivatives, and other hedging activities	[7]																	(88)		(199)		44
Interest Expenses																		417		461		425
Income from Continuing Operations Before Income Taxes																		1,249		1,311		993
Income Taxes	[8]																	128		329		71
Deferred income taxes and investment tax credits	[2]																	45		94		(45)
Net income																		1,121		982		922
Cash Flow [Abstract]
Expenditures for long-lived assets																		1,242		1,438		1,280
Balance Sheet Data
Assets		16,669								15,944								16,669		15,944
Pennsylvania Regulated [Member]
Income Statement Data
Revenues	[5]																	2,124		2,044		1,870
Depreciation																		214		185		178
Amortization	[6]																	26		19		19
Interest Expenses																		130		122		108
Income from Continuing Operations Before Income Taxes																		416		423		317
Income Taxes	[8]																	164		160		108
Deferred income taxes and investment tax credits	[2]																	220		87		127
Net income																		252		263		209
Cash Flow [Abstract]
Expenditures for long-lived assets																		1,107		957		942
Balance Sheet Data
Assets		8,511								7,706								8,511		7,706
Corporate And Other [Member]
Income Statement Data
Revenues	[5]																	20		19		14
Depreciation																		45		47		31
Amortization	[6]																	0		4		6
Interest Expenses																		92		41		33
Income from Continuing Operations Before Income Taxes																		(144)	[9]	(106)	[9]	(66)
Income Taxes	[8]																	(48)	[9]	14	[9]	2
Deferred income taxes and investment tax credits	[2]																	(73)	[9]	36	[9]	51
Net income																		(96)	[9]	(120)	[9]	(68)
Cash Flow [Abstract]
Expenditures for long-lived assets																		11		66		26
Balance Sheet Data
Assets	[10]	365								909								365		909
Discontinued Operations [Member]
Income Statement Data
Net income	[11]																	(921)		300		(240)
Balance Sheet Data
Assets		0								11,025								$ 0		11,025
PPL Electric Utilities Corp [Member]
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer																		2
Number of reportable segments | Integer																		1
Income Statement Data
Revenues		499	[12]	519	[12]	476	[12]	630	[12]	526	[12]	477	[12]	449	[12]	592	[12]	$ 2,124		2,044		1,870
Depreciation																		214		185		178
Amortization																		26		19		19
Interest Expenses																		130		122		108
Income from Continuing Operations Before Income Taxes																		416		423		317
Income Taxes																		164		160		108
Net income		61	[12]	$ 55	[12]	$ 49	[12]	$ 87	[12]	69	[12]	$ 57	[12]	$ 52	[12]	$ 85	[12]	252	[13]	263	[13]	209	[13]
Balance Sheet Data
Assets		8,511								7,706								$ 8,511		7,706
LG And E And KU Energy LLC [Member]
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer																		1
Income Statement Data
Revenues																		$ 3,115		3,168		2,976
Depreciation																		382		354		334
Amortization																		27		25		22
Interest Expenses																		178		167		144
Income from Continuing Operations Before Income Taxes																		603		553		551
Income Taxes																		239		209		206
Net income																		364		344		347
Balance Sheet Data
Assets		14,090								13,356								$ 14,090		13,356
Louisville Gas And Electric Co [Member]
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer																		1
Income Statement Data
Revenues																		$ 1,444		1,533		1,410
Depreciation																		162		157		148
Amortization																		11		12		6
Interest Expenses																		57		49		34
Income from Continuing Operations Before Income Taxes																		299		272		257
Income Taxes																		114		103		94
Net income	[14]																	185		169		163
Balance Sheet Data
Assets		6,068								5,654								$ 6,068		5,654
Kentucky Utilities Co [Member]
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer																		1
Income Statement Data
Revenues																		$ 1,728		1,737		1,635
Depreciation																		220		197		186
Amortization																		13		11		14
Interest Expenses																		82		77		70
Income from Continuing Operations Before Income Taxes																		374		355		360
Income Taxes																		140		135		132
Net income	[13]																	234		220		$ 228
Balance Sheet Data
Assets		$ 8,011								$ 7,701								$ 8,011		$ 7,701
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.
[2]	Represents a non-cash expense item that is also incl uded in "Income Taxes.”
[3]	The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information.
[4]	(f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
[5]	See Note 1 for additional information on Operating Revenues.
[6]	Represents non-cash expense items that include amortization of regulatory assets, debt discounts and premiums, debt issuance costs, emission allowances and RECs.
[7]	Includes unrealized gains and losses from economic activity. See Note 17 for additional information.
[8]	Represents both current and deferred income taxes , including investment tax credits.
[9]	2015 and 2014 include certain costs related to the spinoff of PPL Energy Supply, including deferred income tax expense, transition cost s and separation benefits for PPL Services employees. See Note 8 for additional information.
[10]	Primarily consists of unallocated items, including cash, PP&E and the elimination of inter-segment transactions.
[11]	2015 includes an $879 million loss on the spinoff of PPL Energy Supply and five months of Supply segment earnings. 2014 includes a gain of $237 million ($137 million after-tax) on the sale of the Montana hydroelectric gener ating facilities. 2013 includes a charge of $697 million ($413 million after-tax) for the termination of the lease of the Colstrip coal-fired electric generating facility. See Note 8 for additional information on these transactions.
[12]	PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.
[13]	Net income approximates comprehensive income.
[14]	Net income equals comprehensive income.

Segment and Related Informati58

Segment and Related Information (Geographic Data) (Details) - USD ($) $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014		Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers	$ 1,780	[1]	$ 1,878		$ 1,781		$ 2,230		$ 1,946	[1]	$ 1,879		$ 1,849		$ 2,178		$ 7,669	$ 7,852	$ 7,263
Long-lived assets	31,056								28,832								31,056	28,832
US [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers																	5,259	5,231	4,860
Long-lived assets	18,569								16,890								18,569	16,890
UK [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers																	2,410	2,621	$ 2,403
Long-lived assets	$ 12,487								$ 11,942								$ 12,487	$ 11,942
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.

Preferred Securities (Details)

Preferred Securities (Details) - $ / shares	Dec. 31, 2015	Oct. 31, 2013
Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	10,000,000
PPL Electric Utilities Corp [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	20,629,936
PPL Electric Utilities Corp [Member] | Preference Stock [Member]
Preferred Securities [Line Items]
Shares authorized		10,000,000
Louisville Gas And Electric Co [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	1,720,000
Par value of stock	$ 25
Louisville Gas And Electric Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	6,750,000
No par value of stock
Kentucky Utilities Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	5,300,000
No par value of stock
Kentucky Utilities Co [Member] | Preference Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	2,000,000
No par value of stock

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		3 Months Ended																12 Months Ended
		Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Income (Numerator)
Income from continuing operations after income taxes		$ 405		$ 396		$ 250		$ 552		$ 408		$ 410		$ 230		$ 389		$ 1,603	$ 1,437		$ 1,368
Less amounts allocated to participating securities																		6	7		7
Income from continuing operations after income taxes available to PPL common shareowners - Basic																		1,597	1,430		1,361
Plus interest charges (net of tax) related to Equity Units																		0	9	[2]	44	[2]
Income from continuing operations after income taxes available to PPL common shareowners - Diluted																		1,597	1,439		1,405
Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted		(6)		(3)		(1,007)	[3],[4]	95	[3]	287	[3],[5]	87	[3]	(1)	[3]	(73)	[3]	(921)	300		(238)
Net income		$ 399		$ 393		$ (757)	[4]	$ 647		$ 695	[5]	$ 497		$ 229		$ 316		682	1,737		1,130
Less amounts allocated to participating securities																		2	9		6
Net income available to PPL common shareowners - Basic																		680	1,728		1,124
Plus interest charges (net of tax) related to Equity Units																		0	9	[2]	44	[2]
Net income available to PPL common shareowners - Diluted																		$ 680	$ 1,737		$ 1,168
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)																		669,814	653,504		608,983
Add incremental non-participating securities:
Share-based payment awards (in shares)	[6]																	2,772	1,910		1,062
Equity Units (in shares)																		0	10,559	[2]	52,568	[2]
Forward sale agreements and Purchase Contracts (in shares)																		0	0		460	[6]
Weighted-average shares - Diluted EPS (in shares)																		672,586	665,973		663,073
Basic EPS - Available to PPL common shareowners:
Income from continuing operations after income taxes (in dollars per share)		$ 0.6	[7]	$ 0.59	[7]	$ 0.37	[7]	$ 0.83	[7]	$ 0.62	[7]	$ 0.61	[7]	$ 0.35	[7]	$ 0.61	[7]	$ 2.38	$ 2.19		$ 2.24
Income (loss) from discontinued operations (net of income taxes) (in dollars per share)																		(1.37)	0.45		(0.39)
Net Income (in dollars per share)		0.59	[7]	0.58	[7]	(1.13)	[7]	0.97	[7]	1.04	[7]	0.74	[7]	0.35	[7]	0.5	[7]	1.01	2.64		1.85
Diluted EPS - Available to PPL common shareowners:
Income from continuing operations after income taxes (in dollars per share)		0.6	[7]	0.59	[7]	0.37	[7]	0.82	[7]	0.62	[7]	0.61	[7]	0.34	[7]	0.61	[7]	2.37	2.16		2.12
Income (loss) from discontinued operations (net of income taxes) (in dollars per share)																		(1.36)	0.45		(0.36)
Net Income (in dollars per share)		$ 0.59	[7]	$ 0.58	[7]	$ (1.13)	[7]	$ 0.96	[7]	$ 1.04	[7]	$ 0.74	[7]	$ 0.34	[7]	$ 0.49	[7]	$ 1.01	$ 2.61		$ 1.76
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	[8]																	4,853
Common stock issued under DRIP (in shares)																		1,728
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS																		1,087	1,816		4,446
Performance Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS																		36	5		55
Restricted Stock Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS																		0	31		29
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.
[2]	In 2014 and 2013, t he If-Converted Method was applied to the Equ ity Units prior to settlement . See Note 7 for additional information on the Equity Units, including the issuance of PPL common stock to settle the Purchase contracts.
[3]	In the second quarter of 2015, PPL completed the spinoff of PPL Energy Supply sub stantially representing PPL's Supply segment. Accordingly, the previously reported operating results for PPL’s Supply segment have been reclassified as discontinued operations. See Note 8 to the Financial Statements for additional information.
[4]	The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information.
[5]	(f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
[6]	The Treasury Stock Method was applied to non-participating share-based payment awards and forward sale agreement s.
[7]	The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.
[8]	Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.

Income and Other Taxes (Deferre

Income and Other Taxes (Deferred Tax Assets and Liabilities and Loss Carryforwards) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013
Income (Loss) from Continuing Operations (Details) [Abstract]
Domestic income		$ 968		$ 922	$ 669
Foreign income		1,100		1,207	1,059
Income Before Income Taxes		2,068		2,129	1,728
Deferred Tax Assets
Deferred investment tax credits		50		52
Regulatory obligations		123		131
Accrued pension costs		217		200
Federal loss carryforwards	[1]	587		129
State loss carryforwards	[2]	319		225
Federal and state tax credit carryforwards		201		196
Foreign capital loss carryforwards		387		446
Foreign loss carryforwards		4		6
Foreign - pensions		171		182
Foreign - regulatory obligations		12		23
Foreign - other		8		11
Contributions in aid of construction		139		138
Domestic - other		209		194
Unrealized losses on qualifying derivatives		15		46
Valuation allowances	[2]	(662)		(622)
Total deferred tax assets		1,780		1,357
Deferred Tax Liabilities
Domestic plant - net		3,875		3,079
Taxes recoverable through future rates		162		156
Other regulatory assets		332		322
Reacquired debt costs		28		31
Foreign plant - net		777		854
Domestic - other		24		17
Total deferred tax liabilities		5,198		4,459
Net deferred tax liability		3,418		3,102
State loss carryforwards and related valuation allowances previously reflected on the PPL Energy Supply segment		77
Federal [Member]
Loss carryforwards
Net operating losses	[3]	1,660
Charitable contributions		$ 15
Expiration - charitable contributions		Dec. 31, 2020
Federal [Member] | Minimum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2029
Federal [Member] | Maximum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2035
State [Member]
Loss carryforwards
Net operating losses	[3],[4]	$ 5,269
Charitable contributions		34
Loss carryfoward valuation allowance on net operating losses		$ 254
State [Member] | Minimum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2017
Expiration - charitable contributions		Dec. 31, 2016
State [Member] | Maximum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2035
Expiration - charitable contributions		Dec. 31, 2020
Foreign [Member]
Loss carryforwards
Net operating losses	[5]	$ 21
Capital losses	[6]	2,152
Loss carryfoward valuation allowance on net operating losses		4
Loss carryfoward valuation allowance on capital losses		387
Other Noncurrent Assets [Member]
Deferred Tax Liabilities
State deferred tax assets		22
PPL Electric Utilities Corp [Member]
Income (Loss) from Continuing Operations (Details) [Abstract]
Income Before Income Taxes		416		423	317
Deferred Tax Assets
Regulatory obligations		56		39
Accrued pension costs		92		85
Federal loss carryforwards	[7]	146		51
State loss carryforwards		27		30
Contributions in aid of construction		111		110
Domestic - other		87		54
Total deferred tax assets		519		369
Deferred Tax Liabilities
Domestic plant - net		1,803		1,453
Taxes recoverable through future rates		135		132
Other regulatory assets		213		173
Reacquired debt costs		18		20
Domestic - other		13		16
Total deferred tax liabilities		2,182		1,794
Net deferred tax liability		1,663		1,425
PPL Electric Utilities Corp [Member] | Federal [Member]
Loss carryforwards
Net operating losses		411
Charitable contributions		$ 3
Expiration - charitable contributions		Dec. 31, 2020
PPL Electric Utilities Corp [Member] | Federal [Member] | Minimum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2031
PPL Electric Utilities Corp [Member] | Federal [Member] | Maximum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2035
PPL Electric Utilities Corp [Member] | State [Member]
Loss carryforwards
Net operating losses		$ 410
Charitable contributions		$ 13
PPL Electric Utilities Corp [Member] | State [Member] | Minimum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2030
Expiration - charitable contributions		Dec. 31, 2016
PPL Electric Utilities Corp [Member] | State [Member] | Maximum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2032
Expiration - charitable contributions		Dec. 31, 2020
LG And E And KU Energy LLC [Member]
Income (Loss) from Continuing Operations (Details) [Abstract]
Income Before Income Taxes		$ 603		553	551
Deferred Tax Assets
Deferred investment tax credits		50		51
Regulatory obligations		66		92
Accrued pension costs		53		53
Federal loss carryforwards	[8]	280		46
Income taxes due to customers		17		20
State loss carryforwards		35		36
Federal and state tax credit carryforwards		181		182
Domestic - other		55		44
Unrealized losses on qualifying derivatives		18		45
Valuation allowances		(12)		0
Total deferred tax assets		743		569
Deferred Tax Liabilities
Domestic plant - net		2,076		1,639
Other regulatory assets		119		143
Domestic - other		11		12
Total deferred tax liabilities		2,206		1,794
Net deferred tax liability		1,463		1,225
LG And E And KU Energy LLC [Member] | Federal [Member]
Loss carryforwards
Net operating losses		$ 801
LG And E And KU Energy LLC [Member] | Federal [Member] | Minimum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2029
LG And E And KU Energy LLC [Member] | Federal [Member] | Maximum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2035
LG And E And KU Energy LLC [Member] | State [Member]
Loss carryforwards
Net operating losses		$ 934
Capital losses		$ 1
Expiration - capital losses		Dec. 31, 2016
LG And E And KU Energy LLC [Member] | State [Member] | Minimum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2028
LG And E And KU Energy LLC [Member] | State [Member] | Maximum [Member]
Loss carryforwards
Expiration - operating losses		Dec. 31, 2035
Louisville Gas And Electric Co [Member]
Income (Loss) from Continuing Operations (Details) [Abstract]
Income Before Income Taxes		$ 299		272	257
Deferred Tax Assets
Deferred investment tax credits		13		14
Regulatory obligations		38		51
Federal loss carryforwards		76	[9]	0
Income taxes due to customers		17		18
Domestic - other		15		9
Unrealized losses on qualifying derivatives		18		32
Total deferred tax assets		177		124
Deferred Tax Liabilities
Domestic plant - net		896		698
Other regulatory assets		75		90
Accrued pension costs		28		28
Domestic - other		7		8
Total deferred tax liabilities		1,006		824
Net deferred tax liability		829		700
Louisville Gas And Electric Co [Member] | Federal [Member]
Loss carryforwards
Net operating losses		$ 218
Expiration - operating losses		Dec. 31, 2035
Kentucky Utilities Co [Member]
Income (Loss) from Continuing Operations (Details) [Abstract]
Income Before Income Taxes		$ 374		355	$ 360
Deferred Tax Assets
Deferred investment tax credits		36		37
Regulatory obligations		28		41
Federal loss carryforwards		97	[10]	0
Income taxes due to customers		0		2
Domestic - other		7		7
Unrealized losses on qualifying derivatives		0		13
Total deferred tax assets		168		100
Deferred Tax Liabilities
Domestic plant - net		1,164		922
Other regulatory assets		44		53
Domestic - other		6		7
Total deferred tax liabilities		1,214		982
Net deferred tax liability		1,046		$ 882
Kentucky Utilities Co [Member] | Federal [Member]
Loss carryforwards
Net operating losses		$ 279
Expiration - operating losses		Dec. 31, 2035
[1]	Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments.
[2]	Includes $77 million of deferred tax assets related to state loss carryforwards and related valuation allowances previously reflected on the PPL Energy Supply Segment. The deferred tax assets and related valuation allowance remain with PPL after the spino ff.
[3]	Includes an insignificant amount of federal and state net operating loss carryforwards from excess tax deductions related to stock compensation for which a tax benefit will be recorded in Equity when realized.
[4]	A valuation allowance of $254 million has been recorded against the deferred tax assets for these losse s.
[5]	A valuation allowance of $4 million has been recorded against the deferred tax assets for these losses .
[6]	A valuation allowance of $ 387 million has been reco rded against the deferred tax assets for these losses .
[7]	Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments .
[8]	Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to the provision to return adjustments .
[9]	Increase in Federal loss carryforwards primarily relates to the e xtension of bonus depreciation.
[10]	Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation.

Income and Other Taxes (Credit

Income and Other Taxes (Credit Carryforwards and Valuation Allowances and Reserves) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Valuation Allowances and Reserves (Details) [Roll Forward]
Reduction of the valuation allowance as a result of the reduction in the UK statutory income tax rate		$ 44				$ 67
Permanently reinvested cumulative undistributed foreign earnings		4,600		$ 3,700
Valuation Allowance Of Deferred Tax Assets [Member]
Valuation Allowances and Reserves (Details) [Roll Forward]
Balance at beginning of period		622		585		632
Additions charged to income		24		57		25
Additions charged to other accounts		77	[1]	6		0
Deductions		61	[2]	26		72	[2]
Balance at end of period		662		622		585
Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount		$ 125
Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Expiration		Dec. 31, 2025
Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Expiration		Dec. 31, 2028
Alternative Minimum Tax Credit [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount		$ 40
Other [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount	[3]	29
Credit carryforward valuation allowance on other		$ 12
Other [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Expiration		Dec. 31, 2016
Other [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Expiration		Dec. 31, 2035
Other [Member] | State [Member]
Credit carryforwards
Credit carryforwards, amount		$ 5
Expiration		Dec. 31, 2022
LG And E And KU Energy LLC [Member] | Valuation Allowance Of Deferred Tax Assets [Member]
Valuation Allowances and Reserves (Details) [Roll Forward]
Balance at beginning of period		$ 0		4		5
Additions charged to other accounts		12	[4]	0		0
Deductions		0		4	[5]	1	[5]
Balance at end of period		12		$ 0		$ 4
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount		$ 125
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Expiration		Dec. 31, 2025
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Expiration		Dec. 31, 2028
LG And E And KU Energy LLC [Member] | Alternative Minimum Tax Credit [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount		$ 28
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount		$ 27
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Expiration		Dec. 31, 2016
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Expiration		Dec. 31, 2035
LG And E And KU Energy LLC [Member] | Other [Member] | State [Member]
Credit carryforwards
Credit carryforwards, amount		$ 5
Expiration		Dec. 31, 2022
Louisville Gas And Electric Co [Member] | Federal [Member]
Credit carryforwards
Credit carryforwards, amount		$ 1
Louisville Gas And Electric Co [Member] | Federal [Member] | Minimum [Member]
Credit carryforwards
Expiration		Dec. 31, 2031
Louisville Gas And Electric Co [Member] | Federal [Member] | Maximum [Member]
Credit carryforwards
Expiration		Dec. 31, 2035
Louisville Gas And Electric Co [Member] | State [Member]
Credit carryforwards
Credit carryforwards, amount		$ 2
Expiration		Dec. 31, 2022
Kentucky Utilities Co [Member] | State [Member]
Credit carryforwards
Credit carryforwards, amount		$ 2
Expiration		Dec. 31, 2022
[1]	Valuation allowance related to deferred tax assets previously reflected on the PPL Energy Supply Segment. The deferred tax assets and related valuation allowance remain with PP L after the spinoff.
[2]	The reductions of the U.K. statutory income tax rates in 2015 and 2013 resulted in $44 million and $67 million in reductions in deferred tax assets and the corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for more information on the impact of the U.K. Finance Acts 2015 and 2013.
[3]	A valuation allowance of $ 12 million has been recorded against the deferred tax assets for these credits .
[4]	Represents tax credits expiring in 2016 through 2020 that are more likely than not to expire before being utilized.
[5]	Primarily related to the expiration of state capital loss carryforwards .

Income and Other Taxes (Income

Income and Other Taxes (Income Tax Expense and Reconciliation of Income Tax Expense) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Income Tax Expense (Benefit)
Current - Federal		$ (26)		$ 18		$ (102)
Current - State		25		26		0
Current - Foreign		89		152		181
Total Current Expense (Benefit)		88		196		79
Deferred - Federal		699		299		259
Deferred - State		68		120		84
Deferred - Foreign		41		96		(53)
Total Deferred Expense (Benefit), excluding operating loss carry forwards		808		515		290
Investment tax credit, net - Federal		(4)		(5)		(5)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	[1]	(396)		8		14
Deferred - State		(31)		(22)		(18)
Total Tax Expense (Benefit) of Operating Loss Carryforwards		(427)		(14)		(4)
Total income tax from continuing operations		465		692		360
Income tax expense (benefit) from continuing operations [Abstract]
Total income tax expense - Federal		273		320		166
Total income tax expense - State		62		124		66
Total income tax expense - Foreign		130		248		128
Total income tax from continuing operations		465		692		360
Discontinued operations		(30)		198		(180)
Stock-based compensation recorded to Additional Paid-in Capital		0		(4)		(2)
Valuation allowance on state deferred taxes related to issuance costs of Purchase Contracts recorded to Additional Paid-in Capital		0		0		(2)
Other comprehensive income		(2)		(190)		159
Valuation allowance on state deferred taxes recorded to other comprehensive income		(4)		0		(7)
Total income tax expense (benefits) excluded from incomes taxes from continuing operations		(36)		4		(32)
Reconciliation of Income Tax Expense
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%		$ 724		$ 745		$ 605
Federal statutory rate		35.00%		35.00%		35.00%
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		$ 31		$ 28		$ 17
Valuation allowance adjustments	[2]	24		55		24
Impact of lower U.K. income tax rates	[3]	(176)		(180)		(144)
U.S. income tax on foreign earnings - net of foreign tax credit	[4]	8		63		21
Federal and state tax reserve adjustments		(22)	[5]	(1)		(49)	[5]
Impact of the United Kingdom Finance Acts on deferred tax balances	[3]	(91)		(1)		(97)
Depreciation not normalized		(5)		(7)		(8)
State deferred tax rate change		0		(1)	[6]	15	[6]
Interest benefit on United Kingdom financing entities		(20)		(5)		(7)
Other		(8)		(4)		(17)
Total increase (decrease)		(259)		(53)		(245)
Total income tax from continuing operations		$ 465		$ 692		$ 360
Effective income tax rate		22.50%		32.50%		20.80%
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized		$ 12
Expense related to federal tax credit carryforwards that are expected to expire as a result of future taxable earnings		$ 12
Adjustment to valuation allowance on deferred tax assets due to spinoff anouncement				$ 50
Expense related to a deferred tax valuation allowance due to a decrease in projected future taxable income						$ 23
United Kingdom statutory income tax rate in effect during period prior to a change		20.00%				23.00%
United Kingdom statutory income tax rate reduction in year one						21.00%
United Kingdom statutory income tax rate reduction in year two		19.00%				20.00%
United Kingdom statutory income tax rate reduction in year five		18.00%
Expense from increased taxable dividends				47		$ 28
Expense (benefit) related to the recalculation of 2010 United Kingdom earnings and profits						(19)
Benefit recorded in continuing operations related to the settlement of the IRS audit for tax years 1998-2011		$ 12
Benefit from favorable United States Tax Court decision on deductibility of United Kingdom windfall profit tax						(44)
Interest portion of benefit from favorable United States Tax Court decision on deductibility of United Kingdom windfall profit tax						19
Benefit recorded related to stranded cost securitization included in change in federal and state income tax reserves						(7)
Taxes, other than income
State gross receipts		89	[7]	102		98
Foreign property		148		157		147
Domestic property and other		62		58		53
Total		299		317		298
Previously recorded reserves		17
PPL Electric Utilities Corp [Member]
Income Tax Expense (Benefit)
Current - Federal		(80)		60		(15)
Current - State		23		15		(4)
Total Current Expense (Benefit)		(57)		75		(19)
Deferred - Federal		287		70		109
Deferred - State		12		16		16
Total Deferred Expense (Benefit), excluding operating loss carry forwards		299		86		125
Investment tax credit, net - Federal		0		(1)		(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal		(75)		0		4
Deferred - State		(3)		0		(1)
Total Tax Expense (Benefit) of Operating Loss Carryforwards		(78)		0		3
Total income tax from continuing operations		164		160		108
Income tax expense (benefit) from continuing operations [Abstract]
Total income tax expense - Federal		132		129		97
Total income tax expense - State		32		31		11
Total income tax from continuing operations		164		160		108
Reconciliation of Income Tax Expense
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%		$ 146		$ 148		$ 111
Federal statutory rate		35.00%		35.00%		35.00%
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		$ 25		$ 22		$ 16
Federal and state tax reserve adjustments		2		(1)		(9)	[8]
Federal and state income tax return adjustments		(2)		1		(1)
Depreciation not normalized		(4)		(6)		(6)
Other		(3)		(4)		(3)
Total increase (decrease)		18		12		(3)
Total income tax from continuing operations		$ 164		$ 160		$ 108
Effective income tax rate		39.40%		37.80%		34.10%
Benefit recorded related to stranded cost securitization included in change in federal and state income tax reserves						$ 7
Taxes, other than income
State gross receipts		$ 89	[9]	$ 102		98
Domestic property and other		5		5		5
Total		94		107		103
Previously recorded reserves		17
LG And E And KU Energy LLC [Member]
Income Tax Expense (Benefit)
Current - Federal		2		(247)		(59)
Current - State		1		8		10
Total Current Expense (Benefit)		3		(239)		(49)
Deferred - Federal		405		437		244
Deferred - State		32		23		20
Total Deferred Expense (Benefit), excluding operating loss carry forwards		437		460		264
Investment tax credit, net - Federal		(3)		(4)		(4)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal		(198)		(8)		(4)
Deferred - State		0		0		(1)
Total Tax Expense (Benefit) of Operating Loss Carryforwards		(198)		(8)		(5)
Total income tax from continuing operations		239		209		206
Income tax expense (benefit) from continuing operations [Abstract]
Total income tax expense - Federal		206		178		177
Total income tax expense - State		33		31		29
Total income tax from continuing operations		239		209		206
Discontinued operations		0		0		1
Other comprehensive income		(1)		(36)		18
Reconciliation of Income Tax Expense
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%		$ 211		$ 194		$ 193
Federal statutory rate		35.00%		35.00%		35.00%
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		$ 22		$ 20		$ 20
Valuation allowance adjustments		12	[10]	0		0
Amortization of investment tax credit		(3)		(4)		(4)
Other		(3)		(1)		(3)
Total increase (decrease)		28		15		13
Total income tax from continuing operations		$ 239		$ 209		$ 206
Effective income tax rate		39.60%		37.80%		37.40%
Taxes, other than income
Domestic property and other		$ 57		$ 52		$ 48
Total		57		52		48
Louisville Gas And Electric Co [Member]
Income Tax Expense (Benefit)
Current - Federal		(15)		(25)		52
Current - State		3		10		16
Total Current Expense (Benefit)		(12)		(15)		68
Deferred - Federal		190		114		33
Deferred - State		13		6		(2)
Total Deferred Expense (Benefit), excluding operating loss carry forwards		203		120		31
Investment tax credit, net - Federal		(1)		(2)		(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal		(76)		0		(3)
Total Tax Expense (Benefit) of Operating Loss Carryforwards		(76)		0		(3)
Total income tax from continuing operations		114		103		94
Income tax expense (benefit) from continuing operations [Abstract]
Total income tax expense - Federal		98		87		80
Total income tax expense - State		16		16		14
Total income tax from continuing operations		114		103		94
Reconciliation of Income Tax Expense
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%		$ 105		$ 95		$ 90
Federal statutory rate		35.00%		35.00%		35.00%
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		$ 11		$ 10		$ 10
Amortization of investment tax credit		(1)		(2)		(2)
Other		(1)		0		(4)
Total increase (decrease)		9		8		4
Total income tax from continuing operations		$ 114		$ 103		$ 94
Effective income tax rate		38.10%		37.90%		36.60%
Taxes, other than income
Domestic property and other		$ 28		$ 25		$ 24
Total		28		25		24
Kentucky Utilities Co [Member]
Income Tax Expense (Benefit)
Current - Federal		(21)		(95)		51
Current - State		1		6		12
Total Current Expense (Benefit)		(20)		(89)		63
Deferred - Federal		240		212		66
Deferred - State		19		14		8
Total Deferred Expense (Benefit), excluding operating loss carry forwards		259		226		74
Investment tax credit, net - Federal		(2)		(2)		(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal		(97)		0		(3)
Total Tax Expense (Benefit) of Operating Loss Carryforwards		(97)		0		(3)
Total income tax from continuing operations		140		135		132
Income tax expense (benefit) from continuing operations [Abstract]
Total income tax expense - Federal		120		115		112
Total income tax expense - State		20		20		20
Total income tax from continuing operations		140		135		132
Other comprehensive income		(1)		(1)		1
Reconciliation of Income Tax Expense
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%		$ 131		$ 124		$ 126
Federal statutory rate		35.00%		35.00%		35.00%
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		$ 13		$ 13		$ 14
Amortization of investment tax credit		(2)		(2)		(2)
Other		(2)		0		(6)
Total increase (decrease)		9		11		6
Total income tax from continuing operations		$ 140		$ 135		$ 132
Effective income tax rate		37.40%		38.00%		36.70%
Taxes, other than income
Domestic property and other		$ 29		$ 27		$ 24
Total		$ 29		$ 27		$ 24
[1]	Increase in Federal loss carryforwards primarily relates to the extension of bonus depreciation and the impact of bonus depreciation related to provision to return adjustments.
[2]	During 2015, PPL recorded $24 million of deferred income tax expense related to deferred tax valuation allowances. PPL recorded state deferred income tax expense of $12 million primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized and $12 million of federal deferred income tax expense primarily related to federal tax credit carryforwards that are expected to expire as a result of lower future taxable earnings due to the extension of bonus depr eciation. As a result of the PPL Energy Supply spinoff announcement, PPL recorded $50 million of deferred income tax expense during 2014 to adjust the valuation allowance on deferred tax assets primarily for state net operating loss carryforwards that we re previously supported by the future earnings of PPL Energy Supply. See Note 8 for additional information on the spinoff. During 2013, PPL recorded $23 million of state deferred income tax expense related to a deferred tax valuation allowance primarily due to a decrease in projected future taxable income at PPL Energy Supply over the remaining carryforward period of Pennsylvania net operating losses.
[3]	The U.K. Finance Act 2015 , enacted in November 2015 , reduced the U.K. statutory income tax rate f rom 20% to 1 9% effective April 1, 2017 and from 19 % to 18% effective April 1, 2020 . As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2015 related to both rate decreases. The U.K. Finance Act 2013, enact ed in July 2013, reduced the U.K. statutory income tax rate from 23% to 21% effective April 1, 2014 and from 21% to 20% effective April 1, 2015. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2013 re lated to both rate decreases.
[4]	During 2015, PPL recorded lower income taxes primarily attributable to a decrease in taxable dividends. During 2014, PPL recorded $47 million of income tax expense primarily attributable to taxable dividends. During 20 13, PPL recorded $28 million of income tax expense resulting from increased taxable dividends offset by a $19 million income tax benefit associated with a ruling obtained from the IRS impacting the recalculation of 2010 U.K. earnings and profits that was r eflected on an amended 2010 U.S. tax return.
[5]	In 2015, PPL recorded a $12 million tax benefit related to the settlement of the IRS audit for the tax years 1998-2011. In May 2013, the Supreme Court ruled that the U.K. Windfall Profits Tax (WPT) imposed on privatized utilities, including WPD, is a creditable tax for U.S. federal income tax purposes. As a result of the Supreme Court ruling, PPL recorded a tax benefit of $44 million during 2013, of which $19 million relates to int erest. In 2013, PPL r ecorded a federal and state income tax reserve benefit of $7 million related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization was zero.
[6]	During each period, PPL recorded adjustments related to its December 31 state deferred tax liabilities as a result of annual changes in state apportionment and the impact on the future estimated state income tax rate .
[7]	The decrease in 2015 was primarily due to the settlement of a 2011 gross receipts tax audit resulting in the reversal of $17 million of previously recognized reserves.
[8]	PPL Electric recorded a tax benefit of $7 million during 2013 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization wa s zero.
[9]	The decrease in 2015 was primarily due to the settlement of a 2011 gross receipts tax audit resulting in the reversal of $17 million of previously recognized reserves.
[10]	Represents a valuation allowance against tax credits expiring from 2016 through 2020 that are more likely than not to expire before being utilized.

Income and Other Taxes (Unrecog

Income and Other Taxes (Unrecognized to End) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)Integer
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed	4
Income Tax Other (Numeric) [Abstract]
Benefit recorded related to the settlement of the IRS audit for tax years 1998-2011 | $	$ 24
Benefit recorded in continuing operations related to the settlement of the IRS audit for tax years 1998-2011 | $	$ 12
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2010 and prior
United Kingdom - Foreign [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2012 and prior
PPL Electric Utilities Corp [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed	2
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
PPL Electric Utilities Corp [Member] | Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
LG And E And KU Energy LLC [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed	2
LG And E And KU Energy LLC [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
LG And E And KU Energy LLC [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2010 and prior
Louisville Gas And Electric Co [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed	2
Louisville Gas And Electric Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
Louisville Gas And Electric Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2010 and prior
Kentucky Utilities Co [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed	2
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2011 and prior
Kentucky Utilities Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2010 and prior

Utility Rate Regulation (Regula

Utility Rate Regulation (Regulatory Assets) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Current regulatory assets	[1]	$ 48	$ 37
Noncurrent regulatory assets		1,733	1,562
Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets		24	5
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets		1	15
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets		10	6
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		809	720
Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		326	316
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		93	124
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		68	77
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		141	122
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		137	114
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		143	79
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets		13	11
Noncurrent regulatory assets		16	10
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets		13	12
Noncurrent regulatory assets		1,006	897
PPL Electric Utilities Corp [Member] | Transmission Service Charge [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		469	372
PPL Electric Utilities Corp [Member] | Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		326	316
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		30	46
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		42	49
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		137	114
PPL Electric Utilities Corp [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets		3	6
Noncurrent regulatory assets		2	0
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current regulatory assets		35	25
Noncurrent regulatory assets		727	665
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets		24	5
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets		1	15
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		340	348
LG And E And KU Energy LLC [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		63	78
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		26	28
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		141	122
LG And E And KU Energy LLC [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		143	79
LG And E And KU Energy LLC [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		6	0
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets		0	4
LG And E And KU Energy LLC [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets		1	0
LG And E And KU Energy LLC [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets		9	1
Noncurrent regulatory assets		8	10
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets		16	21
Noncurrent regulatory assets		424	397
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets		13	4
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets		1	15
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		215	215
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		35	43
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		17	18
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		98	89
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		57	28
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets		0	2
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets		1	0
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets		1	0
Noncurrent regulatory assets		2	4
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets		19	4
Noncurrent regulatory assets		303	268
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets		11	1
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		125	133
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		28	35
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		9	10
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		43	33
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		86	51
Kentucky Utilities Co [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets		6	0
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets		0	2
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets		8	1
Noncurrent regulatory assets		$ 6	$ 6
[1]	For PPL, these amounts are included in "Other current assets" on the Balance Sheets.

Utility Rate Regulation (Regu66

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Current regulatory liabilities		$ 145	$ 91
Noncurrent regulatory liabilities		945	992
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		41	28
Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		8	2
Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		6	6
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		48	42
Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		14	0
Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		16	3
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		691	693
Coal Contracts [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	17	59
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	83	92
Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		23	26
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		22	18
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		24	16
Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		82	84
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		12	10
Noncurrent regulatory liabilities		3	4
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		113	76
Noncurrent regulatory liabilities		22	18
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		41	28
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		48	42
PPL Electric Utilities Corp [Member] | Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		16	3
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		22	18
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		8	3
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		32	15
Noncurrent regulatory liabilities		923	974
LG And E And KU Energy LLC [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		8	2
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		6	6
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		14	0
LG And E And KU Energy LLC [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	3
LG And E And KU Energy LLC [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		691	693
LG And E And KU Energy LLC [Member] | Coal Contracts [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	17	59
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	83	92
LG And E And KU Energy LLC [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		23	26
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		24	16
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		82	84
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		4	4
Noncurrent regulatory liabilities		3	4
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		13	10
Noncurrent regulatory liabilities		431	458
Louisville Gas And Electric Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		4	1
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		6	6
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		2	0
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	3
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		301	302
Louisville Gas And Electric Co [Member] | Coal Contracts [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	7	25
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	57	63
Louisville Gas And Electric Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		23	24
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		41	42
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		1	0
Noncurrent regulatory liabilities		2	2
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		19	5
Noncurrent regulatory liabilities		492	516
Kentucky Utilities Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		4	1
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		12	0
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		390	391
Kentucky Utilities Co [Member] | Coal Contracts [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	10	34
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	[1]	26	29
Kentucky Utilities Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	2
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		24	16
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		41	42
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		3	4
Noncurrent regulatory liabilities		$ 1	$ 2
[1]	These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acq uisition of LKE by PPL.

Utility Rate Regulation (Regu67

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2015USD ($)Integer	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		$ 101	$ 0	$ 0
Net cash settlements on terminated interest rate swaps		$ 0	0	104
Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period for the deferred recovery of a regulatory asset		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Regulatory asset costs expected to be amortized into net periodic defined benefit costs in the next year		$ 46
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		10
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period to be recorded as a regulatory asset in 2016		$ 10
Unamortized Loss On Debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2040
Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]
Return on equity for approved projects remaining from earlier ECR plans		10.00%
Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date for the deferred recovery of a regulatory liability		Dec. 31, 2043
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		$ 88
Net cash settlements on terminated interest rate swaps				86
Coal Contracts [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2016
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Mar. 31, 2026
Plant Retirement Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		3 years
PPL Electric [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		five-year
PPL Electric [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		three-year
Amortization end date		May 31, 2016
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]
Maximum recoverable cost		$ 250
Maximum recoverable cost Phase II		$ 185
LGE [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 18 months
LGE [Member] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2033
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Amortization end date for 2008 terminated swap contract		Dec. 31, 2035
LGE [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		10.00%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Term, in years, of the gas service rider program | Integer		5
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Regulatory asset costs expected to be amortized into net periodic defined benefit costs in the next year		$ 18
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		three years
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2029
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		five-year
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		three-year
Amortization end date		May 31, 2016
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]
Maximum recoverable cost		$ 250
Maximum recoverable cost Phase II		185
LG And E And KU Energy LLC [Member]
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		(9)
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		88	0	0
Net cash settlements on terminated interest rate swaps		$ 0	0	86
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period for the deferred recovery of a regulatory asset		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Regulatory asset costs expected to be amortized into net periodic defined benefit costs in the next year		$ 28
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		10
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period to be recorded as a regulatory asset in 2016		$ 10
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2040
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]
Return on equity for approved projects remaining from earlier ECR plans		10.00%
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date for the deferred recovery of a regulatory liability		Dec. 31, 2043
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		$ 88
Net cash settlements on terminated interest rate swaps				86
LG And E And KU Energy LLC [Member] | Coal Contracts [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2016
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Mar. 31, 2026
LG And E And KU Energy LLC [Member] | LGE [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 18 months
LG And E And KU Energy LLC [Member] | LGE [Member] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2033
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Amortization end date for 2008 terminated swap contract		Dec. 31, 2035
LG And E And KU Energy LLC [Member] | LGE [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		10.00%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Term, in years, of the gas service rider program | Integer		5
LG And E And KU Energy LLC [Member] | KU [Member] | Plant Retirement Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		3 years
Louisville Gas And Electric Co [Member]
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (3)
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		44	0	0
Net cash settlements on terminated interest rate swaps		$ 0	0	43
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period for the deferred recovery of a regulatory asset		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Regulatory asset costs expected to be amortized into net periodic defined benefit costs in the next year		$ 19
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		6
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period to be recorded as a regulatory asset in 2016		$ 6
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2020
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2035
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Return on equity	10.00%
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]
Return on equity for approved projects remaining from earlier ECR plans		10.00%
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 18 months
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2033
Amortization end date for the deferred recovery of a regulatory liability		Dec. 31, 2043
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		$ 44
Net cash settlements on terminated interest rate swaps				43
Amortization end date for 2008 terminated swap contract		Dec. 31, 2035
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		10.00%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Term, in years, of the gas service rider program | Integer		5
Louisville Gas And Electric Co [Member] | Coal Contracts [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2016
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Mar. 31, 2026
Kentucky Utilities Co [Member]
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		$ 44	0	0
Net cash settlements on terminated interest rate swaps		$ 0	$ 0	43
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period for the deferred recovery of a regulatory asset		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Regulatory asset costs expected to be amortized into net periodic defined benefit costs in the next year		$ 9
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		4
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period to be recorded as a regulatory asset in 2016		$ 4
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2020
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2040
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Return on equity	10.00%
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]
Return on equity for approved projects remaining from earlier ECR plans		10.00%
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		within 12 months
Period of recurring reviews of activity		six-month and two-year
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date for the deferred recovery of a regulatory liability		Dec. 31, 2043
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps		$ 44
Net cash settlements on terminated interest rate swaps				$ 43
Kentucky Utilities Co [Member] | Coal Contracts [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Dec. 31, 2016
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization end date		Mar. 31, 2026
Kentucky Utilities Co [Member] | Plant Retirement Costs [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Amortization period		3 years

Utility Rate Regulation (Regu68

Utility Rate Regulation (Regulatory Matters) (Details) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jan. 29, 2016USD ($)

Nov. 30, 2015USD ($)

Sep. 30, 2015USD ($)

Jun. 30, 2015USD ($)

Mar. 31, 2015USD ($)

Jul. 31, 2014Integer

Sep. 30, 2013Integer

Dec. 31, 2015USD ($)

Dec. 31, 2015USD ($)Integer

Dec. 31, 2014USD ($)Integer

Dec. 31, 2013USD ($)

Mar. 31, 2014USD ($)

Regulatory Matters - United Kingdom Activities - Ofgem Review of Line Loss Calculation (Numeric) [Abstract]

Charge to income during period for line loss incentive/penalty liability

$ 0

$ 65

$ 45

Liability at period end regarding line loss incentive/penalty

$ 61

61

99

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

28,716

$ 28,716

25,207

Defined Benefit Plans [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Amortization period for the deferred recovery of a regulatory asset

15 years

PPL Electric [Member]

Regulatory Matters - Pennsylvania Activities - Distribution System Improvement Charge (Numeric) [Abstract]

Current percentage of billed revenues allowable for the distribution system improvement charge

5.00%

Requested percentage of billed revenues allowable for the distribution system improvement charge

7.50%

Number of issues assigned to the Office of Administrative Law Judge | Integer

4

Regulatory Matters - Pennsylvania Activities - Storm Damage Expense Rider (Numeric) [Abstract]

Maximum reportable storm damage expenses to be recovered annually through base rates

$ 15

Amount of amortized storm expense included in base rate component

$ 5

Regulatory Matters - Pennsylvania Activities - Act 129 (Numeric) [Abstract]

Minimum term of long term supply contract under Act 129 (in years) | Integer

4

Maximum term of long term supply contract under Act 129 (in years) | Integer

20

Maximum percentage of long-term contracts that can be included in the mix of PLR supply contracts under Act 129

25.00%

Regulatory Matters - Pennsylvania Activities - Smart Meter Rider (Numeric) [Abstract]

Maximum number of years the cost of smart meters can be depreciated | Integer

15

Projected cost of proposed smart meter replacement project

471

$ 471

Estimated cost for studies on smart meter capabilities

$ 406

$ 406

PPL Electric [Member] | Pennsylvania 2013 Storms [Member]

Regulatory Matters - Pennsylvania Activities - Storm Damage Expense Rider (Numeric) [Abstract]

Amount of regulatory liability reversed

$ 12

PPL Electric [Member] | Hurricane Sandy [Member]

Regulatory Matters - Storm Costs (Numeric) [Abstract]

Amount of regulatory asset established

$ 29

Period over which storm costs will be recovered (in years) | Integer

3

PPL Electric [Member] | Distribution Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 124

Dollar amount requested increase in base rates with anticipated rate case filing

$ 167.5

LGE [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LGE [Member] | Kentucky Public Service Commission [Member]

Regulatory Matters - Kentucky Activities - Kentucky Public Service Commission (Numeric) [Abstract]

Frequency of status report udates

3 months

LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LGE [Member] | Kentucky Public Service Commission [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 7

LGE [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Requested return on equity

10.00%

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 316

KU [Member] | Kentucky Public Service Commission [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Number of years over which deferred costs associated with Green River Units 3 and 4 will be recovered

3 years

Regulatory Matters - Kentucky Activities - Kentucky Public Service Commission (Numeric) [Abstract]

Frequency of status report udates

3 months

KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

KU [Member] | Kentucky Public Service Commission [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 125

KU [Member] | Federal Energy Regulatory Commission [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.25%

Regulatory Matters - Federal Matters - Federal Energy Regulatory Commission Wholesale Formula Rates (Numeric) [Abstract]

Number of municipal customers impacted for Federal Energy Regulatory Commission formula rate request | Integer

12

Number of municipalities that submitted termination notices, effective 2019 | Integer

9

Number of municipalities that submitted termination notices, effective 2017 | Integer

1

Number of municipalities that agreed to settlement terms of rate change request | Integer

2

Requested return on equity for certain wholesale customers

10.70%

10.00%

Refunds issued to remaining municipals and the departing municipals

$ 3.4

$ 3.4

Number of municipalities with an open matter | Integer

1

KU [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Requested return on equity

10.00%

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 678

PPL Electric Utilities Corp [Member]

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

6,161

$ 6,161

$ 5,072

Regulatory Matters - Pennsylvania Activities - Distribution System Improvement Charge (Numeric) [Abstract]

Current percentage of billed revenues allowable for the distribution system improvement charge

5.00%

Requested percentage of billed revenues allowable for the distribution system improvement charge

7.50%

Number of issues assigned to the Office of Administrative Law Judge | Integer

4

Regulatory Matters - Pennsylvania Activities - Storm Damage Expense Rider (Numeric) [Abstract]

Maximum reportable storm damage expenses to be recovered annually through base rates

$ 15

Amount of amortized storm expense included in base rate component

$ 5

Regulatory Matters - Pennsylvania Activities - Act 129 (Numeric) [Abstract]

Minimum term of long term supply contract under Act 129 (in years) | Integer

4

Maximum term of long term supply contract under Act 129 (in years) | Integer

20

Maximum percentage of long-term contracts that can be included in the mix of PLR supply contracts under Act 129

25.00%

Regulatory Matters - Pennsylvania Activities - Smart Meter Rider (Numeric) [Abstract]

Maximum number of years the cost of smart meters can be depreciated | Integer

15

Projected cost of proposed smart meter replacement project

471

$ 471

Estimated cost for studies on smart meter capabilities

406

406

PPL Electric Utilities Corp [Member] | Pennsylvania 2013 Storms [Member]

Regulatory Matters - Pennsylvania Activities - Storm Damage Expense Rider (Numeric) [Abstract]

Amount of regulatory liability reversed

$ 12

PPL Electric Utilities Corp [Member] | Hurricane Sandy [Member]

Regulatory Matters - Storm Costs (Numeric) [Abstract]

Amount of regulatory asset established

$ 29

Period over which storm costs will be recovered (in years) | Integer

3

PPL Electric Utilities Corp [Member] | Distribution Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 124

Dollar amount requested increase in base rates with anticipated rate case filing

$ 167.5

LG And E And KU Energy LLC [Member]

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

10,743

$ 10,743

$ 8,945

LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Amortization period for the deferred recovery of a regulatory asset

15 years

LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member]

Regulatory Matters - Kentucky Activities - Kentucky Public Service Commission (Numeric) [Abstract]

Frequency of status report udates

3 months

LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 7

LG And E And KU Energy LLC [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Requested return on equity

10.00%

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 316

LG And E And KU Energy LLC [Member] | LGE [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Number of years over which deferred costs associated with Green River Units 3 and 4 will be recovered

3 years

Regulatory Matters - Kentucky Activities - Kentucky Public Service Commission (Numeric) [Abstract]

Frequency of status report udates

3 months

LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 125

LG And E And KU Energy LLC [Member] | KU [Member] | Federal Energy Regulatory Commission [Member]

Regulatory Matters - Federal Matters - Federal Energy Regulatory Commission Wholesale Formula Rates (Numeric) [Abstract]

Number of municipal customers impacted for Federal Energy Regulatory Commission formula rate request | Integer

12

Number of municipalities that submitted termination notices, effective 2019 | Integer

9

Number of municipalities that submitted termination notices, effective 2017 | Integer

1

Number of municipalities that agreed to settlement terms of rate change request | Integer

2

Requested return on equity for certain wholesale customers

10.70%

Refunds issued to remaining municipals and the departing municipals

3.4

$ 3.4

Number of municipalities with an open matter | Integer

1

LG And E And KU Energy LLC [Member] | KU [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Requested return on equity

10.00%

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 678

Louisville Gas And Electric Co [Member]

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

4,400

$ 4,400

3,575

Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Amortization period for the deferred recovery of a regulatory asset

15 years

Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]

Regulatory Matters - Kentucky Activities - Kentucky Public Service Commission (Numeric) [Abstract]

Frequency of status report udates

3 months

Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 7

Louisville Gas And Electric Co [Member] | LGE [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Requested return on equity

10.00%

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 316

Kentucky Utilities Co [Member]

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 6,340

$ 6,340

$ 5,366

Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Amortization period for the deferred recovery of a regulatory asset

15 years

Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Number of years over which deferred costs associated with Green River Units 3 and 4 will be recovered

3 years

Regulatory Matters - Kentucky Activities - Kentucky Public Service Commission (Numeric) [Abstract]

Frequency of status report udates

3 months

Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Gas Line Tracker [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.00%

Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Increase in annual revenue requirements associated with base rates resulting from rate case

$ 125

Kentucky Utilities Co [Member] | Federal Energy Regulatory Commission [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Approved return on equity

10.25%

Regulatory Matters - Federal Matters - Federal Energy Regulatory Commission Wholesale Formula Rates (Numeric) [Abstract]

Number of municipal customers impacted for Federal Energy Regulatory Commission formula rate request | Integer

12

Number of municipalities that submitted termination notices, effective 2019 | Integer

9

Number of municipalities that submitted termination notices, effective 2017 | Integer

1

Number of municipalities that agreed to settlement terms of rate change request | Integer

2

Requested return on equity for certain wholesale customers

10.70%

10.00%

Refunds issued to remaining municipals and the departing municipals

$ 3.4

$ 3.4

Number of municipalities with an open matter | Integer

1

Kentucky Utilities Co [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Rate Case Proceeding / Federal Energy Regulatory Commission Formula Rates (Numeric) [Abstract]

Requested return on equity

10.00%

Kentucky Utilities Co [Member] | KU [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]

Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numberic) [Abstract]

Expected capitalized costs

$ 678

Financing Activities (Credit Ar

Financing Activities (Credit Arrangements) (Details) £ in Millions, $ in Millions		1 Months Ended	12 Months Ended
		Jan. 31, 2016GBP (£)	Dec. 31, 2015GBP (£)		Jan. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014GBP (£)		Dec. 31, 2014USD ($)
PPL Electric [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 28, 2019
Capacity	[1],[2]					$ 300
Letters of credit and commercial paper issued						1			$ 1
Unused capacity						$ 299
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
PPL Electric [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Jan. 29, 2021
Capacity					$ 400
Potential capacity increase					250
LKE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Oct. 30, 2018
Capacity	[1],[2]					$ 75
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 25
LKE [Member] | Syndicated Credit Facility [Member] | United States of America, Dollars [Member]
Financing Activities [Line Items]
Borrowed	[1],[3]					$ 75			$ 75
Interest rate on outstanding borrowing			1.68%			1.68%	1.67%		1.67%
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 29, 2019
Capacity	[1],[2]					$ 500
Letters of credit and commercial paper issued						142			$ 264
Unused capacity						$ 358
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
LGE [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Dec. 31, 2020
Potential capacity increase					100
KU [Member]
Financing Activities [Line Items]
Capacity						598
Letters of credit and commercial paper issued						246			434
Unused capacity						352
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 29, 2019
Capacity	[1],[2]					400
Letters of credit and commercial paper issued						48			236
Unused capacity						$ 352
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
KU [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Dec. 31, 2020
Potential capacity increase					100
KU [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Oct. 1, 2017
Capacity	[1],[2],[4]					198
Letters of credit and commercial paper issued	[4]					$ 198			198
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
UK [Member]
Financing Activities [Line Items]
Capacity | £			£ 1,095
Letters of credit and commercial paper issued | £			4				£ 5
Unused capacity			958	[5]		$ 1,400
UK [Member] | United Kingdom, Pounds [Member]
Financing Activities [Line Items]
Borrowed | £	[5]		133				167
UK [Member] | Uncommitted Credit Facilities [Member]
Financing Activities [Line Items]
Capacity | £			40
Letters of credit and commercial paper issued | £			4				5
Unused capacity | £			£ 36
UK [Member] | WPD PLC [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Dec. 1, 2016
Capacity | £	[1],[6]		£ 210
Unused capacity | £			£ 77
Minimum interest coverage ratio allowed under the credit facility			3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility			85.00%			85.00%
UK [Member] | WPD PLC [Member] | Syndicated Credit Facility [Member] | New Facility Subsequent To Period End [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Jan. 13, 2021
Capacity | £		£ 210
UK [Member] | WPD PLC [Member] | Syndicated Credit Facility [Member] | Replaced Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Jan. 13, 2021
Capacity | £		£ 210
UK [Member] | WPD PLC [Member] | Syndicated Credit Facility [Member] | United States of America, Dollars [Member]
Financing Activities [Line Items]
Borrowed			£ 133			$ 200	£ 103		$ 161
Interest rate on outstanding borrowing			1.83%			1.83%	1.86%		1.86%
UK [Member] | WPD South West [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 1, 2020
Capacity | £	[1],[6]		£ 245
Unused capacity | £			£ 245
Minimum interest coverage ratio allowed under the credit facility			3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility			85.00%			85.00%
UK [Member] | WPD East Midlands [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 1, 2020
Capacity | £	[1],[6]		£ 300
Unused capacity | £			£ 300
Minimum interest coverage ratio allowed under the credit facility			3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility			85.00%			85.00%
UK [Member] | WPD East Midlands [Member] | Syndicated Credit Facility [Member] | United Kingdom, Pounds [Member]
Financing Activities [Line Items]
Borrowed							£ 64	[1],[6]	$ 100
Interest rate on outstanding borrowing							1.00%		1.00%
UK [Member] | WPD West Midlands [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 1, 2020
Capacity | £	[1],[6]		£ 300
Unused capacity | £			£ 300
Minimum interest coverage ratio allowed under the credit facility			3.0 times
Maximum percentage of total net debt to RAV allowed under the credit facility			85.00%			85.00%
US [Member] | PPL Capital Funding [Member]
Financing Activities [Line Items]
Capacity						$ 750
Letters of credit and commercial paper issued						471			$ 21
Unused capacity						279
US [Member] | PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Nov. 12, 2018
Capacity	[1],[2]					300
Letters of credit and commercial paper issued	[1]					151
Unused capacity	[1]					$ 149
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 30
US [Member] | PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Jan. 29, 2021
Capacity					700
Potential capacity increase					250
US [Member] | PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 28, 2019
Capacity	[1],[2]					300
Letters of credit and commercial paper issued	[1]					$ 300
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
US [Member] | PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Mar. 26, 2016
Capacity	[1],[2]					150
Letters of credit and commercial paper issued	[1]					20			21
Unused capacity	[1]					$ 130
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 30
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 28, 2019
Capacity	[1],[2]					300
Letters of credit and commercial paper issued						1			1
Unused capacity						$ 299
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Jan. 29, 2021
Capacity					400
Potential capacity increase					250
LG And E And KU Energy LLC [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Oct. 30, 2018
Capacity	[1],[2]					$ 75
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 25
LG And E And KU Energy LLC [Member] | Syndicated Credit Facility [Member] | United States of America, Dollars [Member]
Financing Activities [Line Items]
Borrowed	[1],[3]					$ 75			$ 75
Interest rate on outstanding borrowing			1.68%			1.68%	1.67%		1.67%
LG And E And KU Energy LLC [Member] | LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 29, 2019
Capacity	[1],[2]					$ 500
Letters of credit and commercial paper issued						142			$ 264
Unused capacity						$ 358
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
LG And E And KU Energy LLC [Member] | LGE [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Dec. 31, 2020
Potential capacity increase					100
LG And E And KU Energy LLC [Member] | KU [Member]
Financing Activities [Line Items]
Capacity						598
Letters of credit and commercial paper issued						246			434
Unused capacity						352
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 29, 2019
Capacity	[1],[2]					400
Letters of credit and commercial paper issued						48			236
Unused capacity						$ 352
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Dec. 31, 2020
Potential capacity increase					100
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Oct. 1, 2017
Capacity	[1],[2]					198
Letters of credit and commercial paper issued	[4]					$ 198			198
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 29, 2019
Capacity	[1],[2]					$ 500
Letters of credit and commercial paper issued						142			264
Unused capacity						$ 358
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Dec. 31, 2020
Potential capacity increase					100
Kentucky Utilities Co [Member]
Financing Activities [Line Items]
Capacity						598
Letters of credit and commercial paper issued						246			434
Unused capacity						352
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Jul. 29, 2019
Capacity	[1],[2]					400
Letters of credit and commercial paper issued						48			236
Unused capacity						$ 352
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
Potential capacity increase						$ 100
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Expiration date		Dec. 31, 2020
Potential capacity increase					$ 100
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Expiration date			Oct. 1, 2017
Capacity	[1],[2]					198
Letters of credit and commercial paper issued	[4]					$ 198			$ 198
Maximum percentage of debt to total capitalization allowed under the credit facility			70.00%			70.00%
[1]	Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin.
[2]	The facilities contain a financial covenant requiring debt to total capitalizati on not to exceed 70% for PPL Capital Funding, PPL Electric, LKE, LG&E and KU, as calculated in accordance with the facilities and other customary covenants . Additionally, as it relates to the syndicated and bilateral cre dit facilities and subject to certain conditions, PPL Capital Funding may request that the capacity of its facility expiring in July 2019 be increased by up to $ 100 million and the facilities expiring in November 2018 and March 2016 may be increased by up to $ 30 million, PPL Electric, LG&E and KU each may request up to a $ 100 million increase in its fac ility's capacity and LKE may request up to a $ 25 million increase in its facility's capacity.
[3]	At December 31, 2015 , LKE's interest rate on outstanding borrowings was 1.68% . At December 31, 2014 , LKE’s interest rate on outstanding borrowings was 1.67% .
[4]	KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted t o loans rather than requiring immediate payment.
[5]	WPD plc's amounts borrowed at December 31, 2015 and 2014 were USD-denominated borrowings of $ 200 million and $ 161 million, which bore interest at 1.83% and 1.86% . WPD (East Midlands) amount borrowed at December 31, 2014 was a GBP-denominated borrowing which equated to $ 100 million and bore interest at 1.00% . At December 31, 2015 , the unused capacity under the U.K. credit facilities was approximately $ 1.4 billion .
[6]	The facilities contain financial covenants to maintain an interest coverage ratio of not less than 3.0 times consolidated earnings before income taxes, depreciation and amortization and total net debt not in excess of 85% of its RAV, calculated in accordance with the credit facility.

Financing Activities (Short-ter

Financing Activities (Short-term Debt) (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Short-term Debt [Line Items]
Capacity	$ 1,600
Commercial paper issuances	641	$ 500
Unused capacity	959
PPL Electric [Member]
Short-term Debt [Line Items]
Capacity	300
Commercial paper issuances	0	0
Unused capacity	300
LGE [Member]
Short-term Debt [Line Items]
Capacity	350
Commercial paper issuances	$ 142	$ 264
Weighted-average interest rate	0.71%	0.42%
Unused capacity	$ 208
KU [Member]
Short-term Debt [Line Items]
Capacity	350
Commercial paper issuances	$ 48	$ 236
Weighted-average interest rate	0.72%	0.49%
Unused capacity	$ 302
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Capacity	600
Commercial paper issuances	$ 451	$ 0
Weighted-average interest rate	0.78%
Unused capacity	$ 149
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Capacity	300
Commercial paper issuances	0	0
Unused capacity	300
LG And E And KU Energy LLC [Member] | LGE [Member]
Short-term Debt [Line Items]
Capacity	350
Commercial paper issuances	$ 142	$ 264
Weighted-average interest rate	0.71%	0.42%
Unused capacity	$ 208
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Capacity	350
Commercial paper issuances	$ 48	$ 236
Weighted-average interest rate	0.72%	0.49%
Unused capacity	$ 302
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Capacity	350
Commercial paper issuances	$ 142	$ 264
Weighted-average interest rate	0.71%	0.42%
Unused capacity	$ 208
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Capacity	350
Commercial paper issuances	$ 48	$ 236
Weighted-average interest rate	0.72%	0.49%
Unused capacity	$ 302

Financing Activities (Long-term

Financing Activities (Long-term Debt and Equity Securities) (Details) $ / shares in Units, £ in Millions, $ in Millions

1 Months Ended

12 Months Ended

Nov. 30, 2015GBP (£)

Nov. 30, 2015USD ($)

Oct. 31, 2015USD ($)

Sep. 30, 2015USD ($)

Feb. 28, 2015USD ($)Integer

May. 31, 2014USD ($)$ / sharesshares

Mar. 31, 2014USD ($)

Jul. 31, 2013USD ($)$ / sharesshares

May. 31, 2013USD ($)Integer

Dec. 31, 2015USD ($)$ / sharesshares

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Dec. 31, 2015GBP (£)

Dec. 31, 2015USD ($)

Nov. 30, 2015USD ($)

Debt Instrument [Line Items]

Principal outstanding

$ 18,188

$ 19,171

Fair market value adjustments

37

30

Unamortized premium and (discount), net

[1]

(52)

(28)

Unamortized debt issuance costs

(119)

(125)

Total Long-term Debt

18,054

19,048

Less current portion of Long-term debt

1,000

485

Long-term Debt

17,054

18,563

Aggregate maturities of long-term debt (Details) [Abstract]

2,016

485

2,017

294

2,018

348

2,019

40

2,020

1,301

Thereafter

$ 16,703

Equity Programs (Numeric) [Abstract]

Net proceeds from issuance of common stock

$ 203

1,074

$ 1,411

WPD PLC [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount | £

£ 500

Stated interest rate

3.625%

3.625%

Maturity date (in years)

Nov. 1, 2023

Nov. 1, 2023

Net proceeds from issuance of unsecured debt

£ 495

$ 746

PPL Electric [Member] | Senior Secured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

4.95%

4.95%

Repayment of debt

$ 100

PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | 2001 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

5,800

$ 6,700

PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Pollution Control Revenue Refunding Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount that may be redeemed at a future date

224

Earliest date the company may redeem the debt

Feb. 15, 2015

Principal amount that may be redeemed in whole or in part

90

Earliest date the company may redeem the debt in whole or in part

Oct. 1, 2020

PPL Electric [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 350

Stated interest rate

4.15%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 345

LKE [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

2.125%

2.125%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

Repayment of debt

$ 400

LKE [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate amount of tax-exempt revenue bonds in a term rate mode

418

Aggregate amount of tax-exempt revenue bonds in a variable rate mode

507

Principal amount that may be put back to the issuer

251

LKE [Member] | First Mortgage Bonds [Member] | Insured Auction Rate Securities [Member]

Debt Instrument [Line Items]

Principal outstanding

231

Long-term Debt (Numeric) [Abstract]

Maximum number of days wherein interest rates reset

weekly or every 35 days

LGE [Member] | First Mortgage Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

1.625%

1.625%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

3,700

4,200

LGE [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2025 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 300

Stated interest rate

3.30%

Maturity date (in years)

Oct. 1, 2025

Proceeds from issuance of secured debt

$ 298

LGE [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

4.375%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 248

KU [Member] | First Mortgage Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

1.625%

1.625%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

5,500

5,700

KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2025 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

3.30%

Maturity date (in years)

Oct. 1, 2025

Proceeds from issuance of secured debt

$ 248

KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

4.375%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 248

United States of America, Dollars [Member]

Debt Instrument [Line Items]

Principal outstanding

10,829

$ 11,229

United States of America, Dollars [Member] | Senior Unsecured Notes [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.87%

3.87%

Maturity date of long-term debt range start

[2]

Jun. 1, 2018

Maturity date of long-term date range end

[2]

Mar. 15, 2044

Principal outstanding

3,825

$ 3,425

United States of America, Dollars [Member] | Senior Secured Notes - First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.97%

3.97%

Maturity date of long-term debt range start

[2]

Nov. 30, 2016

Maturity date of long-term date range end

[2]

Oct. 1, 2045

Principal outstanding

[3],[4],[5]

6,074

$ 6,874

United States of America, Dollars [Member] | Junior Subordinated Notes [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

6.31%

6.31%

Maturity date of long-term debt range start

[2]

Mar. 30, 2067

Maturity date of long-term date range end

[2]

Apr. 30, 2073

Principal outstanding

930

$ 930

United Kingdom, Pounds [Member]

Debt Instrument [Line Items]

Principal outstanding

7,359

7,942

[6]

Long-term Debt (Numeric) [Abstract]

Principal amount that may be put back to the issuer

£ 4,400

$ 6,600

United Kingdom, Pounds [Member] | Senior Unsecured Notes [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

5.33%

5.33%

Maturity date of long-term debt range start

[2]

May 1, 2016

Maturity date of long-term date range end

[2]

Dec. 10, 2040

Principal outstanding

6,627

$ 7,170

[7]

Long-term Debt (Numeric) [Abstract]

Principal amount that may be redeemed in total but not in part

£ 225

$ 339

Earliest date the company may redeem the debt in total but not in part

Dec. 21, 2026

United Kingdom, Pounds [Member] | Index Linked Senior Unsecured Notes [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

1.82%

1.82%

Maturity date of long-term debt range start

[2]

Jun. 1, 2043

Maturity date of long-term date range end

[2]

Dec. 1, 2056

Principal outstanding

[1]

732

$ 772

United Kingdom, Pounds [Member] | WPD South West [Member] | Index Linked Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount that may be redeemed in total by series

£ 225

339

Earliest date the company may redeem the debt in total by series

Dec. 1, 2026

Increase (decrease) in principal due to inflation

4

6

United Kingdom, Pounds [Member] | WPD East Midlands [Member] | Index Linked Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Increase (decrease) in principal due to inflation

£ 4

6

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Number of tranches of debt entered into relating to the debt extinguishment | Integer

3

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Senior Unsecured Notes [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

1.90%

Maturity date (in years)

Jun. 1, 2018

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Senior Unsecured Notes [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 600

Stated interest rate

3.40%

Maturity date (in years)

Jun. 1, 2023

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Senior Unsecured Notes [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 300

Stated interest rate

4.70%

Maturity date (in years)

Jun. 1, 2043

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Exchanged [Member]

Long-term Debt (Numeric) [Abstract]

Gain (loss) on extinguishment of debt

$ (10)

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member] | Remarketed [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 1,150

Stated interest rate

4.625%

Maturity date (in years)

Jul. 1, 2018

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member] | Exchanged [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

2.04%

Maturity date (in years)

Jun. 1, 2016

Principal amount extinguished

$ 300

Equity Units 2010 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member] | Exchanged [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

2.77%

Maturity date (in years)

Jun. 1, 2018

Principal amount extinguished

$ 850

Purchase Contacts 2010 [Member]

Equity Programs (Numeric) [Abstract]

Shares of common stock issued during the period | shares

40,000,000

Price per share of PPL common stock issued | $ / shares

$ 28.73

Net proceeds from issuance of common stock

$ 1,150

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Senior Unsecured Notes [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 350

Stated interest rate

3.95%

Maturity date (in years)

Mar. 15, 2024

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Senior Unsecured Notes [Member] | Senior Unsecured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 400

Stated interest rate

5.00%

Maturity date (in years)

Mar. 15, 2044

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member]

Long-term Debt (Numeric) [Abstract]

Gain (loss) on extinguishment of debt

$ (9)

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

4.32%

Maturity date (in years)

May 1, 2019

Portion of total principal settled in cash

$ 228

Principal amount extinguished

228

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member] | Remarketed [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 978

Stated interest rate

4.32%

Maturity date (in years)

May 1, 2019

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member] | Exchanged [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

2.189%

Maturity date (in years)

Mar. 15, 2017

Principal amount extinguished

$ 350

Equity Units 2011 [Member] | PPL Capital Funding [Member] | Junior Subordinated Notes [Member] | Junior Subordinated Notes [Member] | Exchanged [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

3.184%

Maturity date (in years)

Mar. 15, 2019

Principal amount extinguished

$ 400

Purchase Contacts 2011 [Member]

Equity Programs (Numeric) [Abstract]

Shares of common stock issued during the period | shares

31,700,000

Price per share of PPL common stock issued | $ / shares

$ 30.86

Net proceeds from issuance of common stock

$ 978

At The Market Stock Offering Program [Member]

Equity Programs (Numeric) [Abstract]

Shares of common stock issued during the period | shares

1,476,700

Net proceeds from issuance of common stock

$ 49

Number of distribution agreements | Integer

2

Aggregate sales price of common stock based on two separate equity distribution agreements

$ 500

Average price per common share | $ / shares

$ 33.41

PPL Electric Utilities Corp [Member]

Debt Instrument [Line Items]

Principal outstanding

2,614

2,864

Unamortized discount

(12)

(13)

Unamortized debt issuance costs

(21)

(23)

Total Long-term Debt

2,581

2,828

Less current portion of Long-term debt

100

0

Long-term Debt

2,481

2,828

Aggregate maturities of long-term debt (Details) [Abstract]

2,016

0

2,017

0

2,018

0

2,019

0

2,020

100

Thereafter

$ 2,764

PPL Electric Utilities Corp [Member] | Senior Secured Notes [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

4.95%

4.95%

Repayment of debt

$ 100

PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

4.50%

4.50%

Maturity date of long-term debt range start

[2]

Dec. 15, 2020

Maturity date of long-term date range end

[2]

Oct. 1, 2045

Principal outstanding

[3],[5]

2,614

$ 2,864

PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | 2001 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

5,800

6,700

PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Pollution Control Revenue Refunding Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount that may be redeemed at a future date

224

Earliest date the company may redeem the debt

Feb. 15, 2015

Principal amount that may be redeemed in whole or in part

90

Earliest date the company may redeem the debt in whole or in part

Oct. 1, 2020

PPL Electric Utilities Corp [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 350

Stated interest rate

4.15%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 345

LG And E And KU Energy LLC [Member]

Debt Instrument [Line Items]

Principal outstanding

4,585

5,135

Fair market value adjustments

(1)

(1)

Unamortized discount

(17)

(16)

Unamortized debt issuance costs

(24)

(30)

Total Long-term Debt

4,543

5,088

Less current portion of Long-term debt

900

25

Long-term Debt

3,643

5,063

Aggregate maturities of long-term debt (Details) [Abstract]

2,016

25

2,017

194

2,018

98

2,019

40

2,020

975

Thereafter

$ 3,803

LG And E And KU Energy LLC [Member] | Senior Unsecured Notes [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.97%

3.97%

Maturity date of long-term debt range start

[2]

Nov. 15, 2020

Maturity date of long-term date range end

[2]

Oct. 1, 2021

Principal outstanding

1,125

$ 725

Long-term Debt (Numeric) [Abstract]

Stated interest rate

2.125%

2.125%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

Repayment of debt

$ 400

LG And E And KU Energy LLC [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.58%

3.58%

Maturity date of long-term debt range start

[2]

Nov. 30, 2016

Maturity date of long-term date range end

[2]

Oct. 1, 2045

Principal outstanding

[3]

3,460

$ 4,010

[4]

LG And E And KU Energy LLC [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate amount of tax-exempt revenue bonds in a term rate mode

418

Aggregate amount of tax-exempt revenue bonds in a variable rate mode

507

Principal amount that may be put back to the issuer

251

LG And E And KU Energy LLC [Member] | First Mortgage Bonds [Member] | Insured Auction Rate Securities [Member]

Debt Instrument [Line Items]

Principal outstanding

$ 231

Long-term Debt (Numeric) [Abstract]

Maximum number of days wherein interest rates reset

weekly or every 35 days

LG And E And KU Energy LLC [Member] | Note Payable [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.50%

3.50%

Maturity date of long-term date range end

[2]

Nov. 13, 2025

Principal outstanding

0

$ 400

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 400

Stated interest rate

3.50%

3.50%

Maturity date (in years)

Nov. 13, 2025

Nov. 13, 2025

LG And E And KU Energy LLC [Member] | LGE [Member] | First Mortgage Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

1.625%

1.625%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

LG And E And KU Energy LLC [Member] | LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

3,700

4,200

LG And E And KU Energy LLC [Member] | LGE [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2025 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 300

Stated interest rate

3.30%

Maturity date (in years)

Oct. 1, 2025

Proceeds from issuance of secured debt

$ 298

LG And E And KU Energy LLC [Member] | LGE [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

4.375%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 248

LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

1.625%

1.625%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

5,500

5,700

LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2025 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

3.30%

Maturity date (in years)

Oct. 1, 2025

Proceeds from issuance of secured debt

$ 248

LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

4.375%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 248

Louisville Gas And Electric Co [Member]

Debt Instrument [Line Items]

Principal outstanding

1,359

1,659

Fair market value adjustments

(1)

(1)

Unamortized discount

(5)

(4)

Unamortized debt issuance costs

(8)

(12)

Total Long-term Debt

1,345

1,642

Less current portion of Long-term debt

250

25

Long-term Debt

1,095

1,617

Aggregate maturities of long-term debt (Details) [Abstract]

2,016

25

2,017

194

2,018

98

2,019

40

2,020

0

Thereafter

$ 1,302

Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.36%

3.36%

Maturity date of long-term debt range start

[2]

Nov. 30, 2016

Maturity date of long-term date range end

[2]

Oct. 1, 2045

Principal outstanding

[3]

1,359

$ 1,659

[4]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

1.625%

1.625%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

3,700

4,200

Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate amount of tax-exempt revenue bonds in a term rate mode

391

Aggregate amount of tax-exempt revenue bonds in a variable rate mode

183

Principal amount that may be put back to the issuer

23

Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | Insured Auction Rate Securities [Member]

Debt Instrument [Line Items]

Principal outstanding

135

Long-term Debt (Numeric) [Abstract]

Maximum number of days wherein interest rates reset

weekly or every 35 days

Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2025 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 300

Stated interest rate

3.30%

Maturity date (in years)

Oct. 1, 2025

Proceeds from issuance of secured debt

$ 298

Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

4.375%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 248

Kentucky Utilities Co [Member]

Debt Instrument [Line Items]

Principal outstanding

2,101

2,351

Unamortized discount

(10)

(10)

Unamortized debt issuance costs

(12)

(15)

Total Long-term Debt

2,079

2,326

Less current portion of Long-term debt

250

0

Long-term Debt

1,829

2,326

Aggregate maturities of long-term debt (Details) [Abstract]

2,016

0

2,017

0

2,018

0

2,019

0

2,020

500

Thereafter

$ 1,851

Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Weighted-Average Rate

[2]

3.74%

3.74%

Maturity date of long-term debt range start

[2]

Nov. 1, 2020

Maturity date of long-term date range end

[2]

Oct. 1, 2045

Principal outstanding

[3]

2,101

$ 2,351

[4]

Long-term Debt (Numeric) [Abstract]

Stated interest rate

1.625%

1.625%

Maturity date (in years)

Nov. 15, 2015

Nov. 15, 2015

Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate carrying value of property subject to lien

$ 5,500

5,700

Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]

Long-term Debt (Numeric) [Abstract]

Aggregate amount of tax-exempt revenue bonds in a term rate mode

27

Aggregate amount of tax-exempt revenue bonds in a variable rate mode

324

Principal amount that may be put back to the issuer

228

Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | Insured Auction Rate Securities [Member]

Debt Instrument [Line Items]

Principal outstanding

$ 96

Long-term Debt (Numeric) [Abstract]

Maximum number of days wherein interest rates reset

weekly or every 35 days

Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2025 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

3.30%

Maturity date (in years)

Oct. 1, 2025

Proceeds from issuance of secured debt

$ 248

Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bond Due 2045 [Member]

Long-term Debt (Numeric) [Abstract]

Principal amount

$ 250

Stated interest rate

4.375%

Maturity date (in years)

Oct. 1, 2045

Proceeds from issuance of secured debt

$ 248

[1]

The principal amount of the notes issued by WPD (South West) and WPD (East Midlands) is adjusted based on changes in a specified index, as detailed in the terms of the related indentures. The adjustment to the princi pal amount s from 2014 to 2015 was an increase of approximately £ 4 million ($ 6 million) resulting from inflation . In addition, this amount includes £ 225 million ($ 339 million at Decembe r 31, 2015 ) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026 , at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nomina ted U.K. government bond.

[2]

The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2015 .

[3]

Includ e s PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric 's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $ 6.7 billion and $ 5.8 billion at December 31, 2015 and 2014 . Includes LG&E's first m ortgage bonds that are secured by the lien of t he LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $ 4.2 billion and $ 3.7 billion at December 31, 2015 and 2014 . Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substan tially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $ 5.7 billion and $ 5.5 billion at December 31, 2015 and 2014 .

[4]

Includes LG&E 's and KU 's series of first mortgage bonds that were issued to the respective trustee s of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amount s , contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in ( a ) above. The related tax-exempt revenue bonds wer e issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate . At December 31, 2015 , the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $ 418 million for LKE, comprised of $ 391 million and $ 27 million for LG&E and KU , respectively . At December 31, 2015 , the aggregate tax-exempt revenue bonds issued on be half of LG&E and KU that were in a variable rate mode totaled $ 507 million for LKE, comprised of $ 183 million and $ 324 million for LG&E and KU , respectively . Several series of the tax-exempt revenue bonds are insured by monoline bond insurers whose ratings were reduced due to exposures relating to insurance of sub-prime mortgages. Of the bonds outstanding, $ 231 million are in the form of insured auction rate securities ($ 135 million for LG&E and $ 96 million for KU) , wherein interest rates are reset either weekly or every 35 days via an auction proces s. Beginning in late 2007, the interest rates on these insured bonds began to increase due to investor concerns about the creditworthiness of the bond insurers. During 2008, interest rates increased, and LG&E and KU experienced failed auctions when there were insufficient bids for the bonds. When a failed auction occurs, the interest rate is set pursuant to a formula stipulated in the indenture. As noted above, the instruments governing these auction rate bonds permit LG&E and KU to convert the bonds to other interest rate modes. Certain of the variable rate tax-exempt revenue bonds totaling $ 251 million at December 31, 2015 ($ 23 million for LG&E and $ 228 million for KU) , are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events.

[5]

Includes PPL Electric 's series of senior secured bonds that secure its obligations to make payments with respect to each se ries of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same inte rest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indentur e and are secured as noted in (a ) above. This amount includes $ 224 million that may be rede emed at par beginning in 2015 and $ 90 million that may be redeemed, in whole or in part, at par beginning in October 2020 and are subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes.

[6]

I ncludes £ 4.4 billion ($ 6.6 billion at December 31, 2015 ) of notes tha t may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the n otes are withdrawn by any of the rating agencies (Moody's or S&P) or reduced to a non-investment grade rating of Ba1 or BB+ or lower in connection with a restructu ring event which includes the loss of, or a material adverse change to, the distribution license s under which the issuer operate s .

[7]

I ncludes £ 225 million ($ 339 million at December 31, 2015 ) of notes that may be redeemed, in total but not in part, on December 21, 2026 , at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. G overnment bond.

Financing Activities (Distribut

Financing Activities (Distributions and Capital Contributions) (Details) - USD ($) $ / shares in Units, $ in Billions	Feb. 04, 2016	Nov. 30, 2015	Dec. 31, 2015		Sep. 30, 2015	[1],[2]	Jun. 30, 2015	[1],[2]	Mar. 31, 2015	[1],[2]	Dec. 31, 2014	[1],[2]	Sep. 30, 2014	[1],[2]	Jun. 30, 2014	[1],[2]	Mar. 31, 2014	[1],[2]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Distributions [Line Items]
Quarterly common stock dividend declaration date		2015-11
Dividend payable date of quarterly common stock dividend		Jan. 4, 2016
Current quarterly common stock dividend (in dollars per share)		$ 0.3775	$ 0.3775	[1],[2]	$ 0.3775		$ 0.3725		$ 0.3725		$ 0.3725		$ 0.3725		$ 0.3725		$ 0.3725		$ 1.5	$ 1.49	$ 1.47
Annualized current quarterly common stock dividend (in dollars per share)		$ 1.51
Restricted net assets at end of period			$ 2.7																$ 2.7
Unrestricted assets at the end of period			2.9																$ 2.9
Minimum adjusted equity to total capitalization in order to pay dividends																			30.00%
Subsequent Event [Member]
Distributions [Line Items]
Quarterly common stock dividend declaration date	2016-02
Quarterly common stock dividend (in dollars per share)	$ 0.38
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.52
LG And E And KU Energy LLC [Member]
Distributions [Line Items]
Restricted net assets at end of period			2.7																$ 2.7
Unrestricted assets at the end of period			2.9																$ 2.9
Minimum adjusted equity to total capitalization in order to pay dividends																			30.00%
Louisville Gas And Electric Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			1.1																$ 1.1
Unrestricted assets at the end of period			1.2																$ 1.2
Minimum adjusted equity to total capitalization in order to pay dividends																			30.00%
Kentucky Utilities Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			1.6																$ 1.6
Unrestricted assets at the end of period			$ 1.7																$ 1.7
Minimum adjusted equity to total capitalization in order to pay dividends																			30.00%
[1]	PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future d ividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.
[2]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.

Acquisitions, Development and73

Acquisitions, Development and Divestures (Details) $ in Millions		1 Months Ended				3 Months Ended																7 Months Ended	12 Months Ended
		Jun. 30, 2015USD ($)Integer	Mar. 31, 2015Integer	Nov. 30, 2014USD ($)IntegerMW	Dec. 31, 2013USD ($)	Dec. 31, 2015USD ($)Integer		Sep. 30, 2015USD ($)Integer		Jun. 30, 2015USD ($)Integer		Mar. 31, 2015USD ($)	[1],[2]	Dec. 31, 2014USD ($)		Sep. 30, 2014USD ($)	[1],[2]	Jun. 30, 2014USD ($)	[1],[2]	Mar. 31, 2014USD ($)	[1],[2]	Dec. 31, 2015USD ($)Integer	Dec. 31, 2015USD ($)kVIntegermiMW	Dec. 31, 2014USD ($)Integer	Dec. 31, 2013USD ($)	Jun. 01, 2015USD ($)
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Deferred income tax recorded as result of agreement to adjust valuation allowances																							$ 428	$ 666	$ 387
Continuing Involvement (Details) [Abstract]
Energy purchases																							855	924	856
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Results of Discontinued Operations (Details) [Abstract]
Income tax expense (benefit)																							(30)	198	(180)
Income (Loss) from Discontinued Operations						$ (6)	[1]	$ (3)	[1]	$ (1,007)	[1],[2],[3]	$ 95		$ 287	[1],[2],[4]	$ 87		$ (1)		$ (73)			(921)	300	(238)
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Assets and Liabilities of Discontinued Operations (Details) [Abstract]
Total Current Assets						0								2,592								$ 0	0	2,592
Total Noncurrent Assets						0								8,311								0	0	8,311
Total Current Liabilities						0								2,771								0	0	2,771
Total Noncurrent Liabilities						0								3,953								0	0	3,953
Development Projects [Abstract]
Construction work in progress						1,315								2,532								1,315	$ 1,315	2,532
Susquehanna Roseland Transmission Line [Member]
Development Projects [Abstract]
Total length (in miles) of the expansion project | mi																							150
Capacity (in kilovolts) of a transmission line | kV																							500
Project costs capitalized						$ 648								597								$ 648	$ 648	597
Northeast Pocono Reliability Project [Member]
Development Projects [Abstract]
Total length (in miles) of the expansion project | mi																							58
Capacity (in kilovolts) of a transmission line | kV																							230
Adder to the return on equity incentive denied in ratemaking request (in basis points) | Integer						100																100	100
Expected capital cost of an expansion project						$ 335																$ 335	$ 335
Number of new substations included in request | Integer						3																3	3
Capitalized costs						$ 319								183								$ 319	$ 319	183
Spinoff [Member] | PPL Energy Supply Spinoff [Member]
Divestitures - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Separation benefits																							10	$ 36
Number of employees impacted | Integer																								306
Amount of accrued liability for seperation benefits						13								20								13	13	$ 20
Third-party costs																							45	27
Spinoff [Member] | PPL Energy Supply Spinoff [Member] | Other Operation Maintenance [Member]
Divestitures - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Separation benefits																							8	20
Consulting and other costs																							13	8
Spinoff [Member] | PPL Energy Supply Spinoff [Member] | Discontinued Operations [Member]
Divestitures - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Separation benefits																							2	$ 16
Number of employees impacted | Integer																								112
Amount of accrued liability for seperation benefits																										$ 24
Bank advisory, legal and accounting fees																							$ 32	$ 19
PPL Energy Supply Spinoff [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Spinoff agreement execution date		Jun. 9, 2014
Date of record		May 20, 2015
Effective date of spinoff		Jun. 1, 2015
Certain details of spinoff transaction																							In June 2014, PPL and PPL Energy Supply executed definitive agreements with affiliates of Riverstone to spin off PPL Energy Supply and immediately combine it with Riverstone’s competitive power generation businesses to form a new, stand-alone, publicly traded company named Talen Energy. The transaction was subject to customary closing conditions, including receipt of regulatory approvals from the NRC, FERC, DOJ and PUC, all of which were received by mid-April 2015. On April 29, 2015, PPL’s Board of Directors declared the June 1, 2015 distribution to PPL’s shareowners of record on May 20, 2015 of a newly formed entity, Holdco, which at closing owned all of the membership interests of PPL Energy Supply and all of the common stock of Talen Energy.
Number of shares of Talen common stock for one share of PPL common stock		0.1249
Initial percent ownership in new company, Talen Energy, by PPL shareowners																										65.00%
Initial percent ownership in new company, Talen Energy, by Riverstone Holdings, LLC																										35.00%
Number of approaches | Integer		3
Weighted fair value																										$ 3,205
Number of market approaches | Integer		2
Carrying value of the Supply segment																										4,100
Gain (loss) on interest rate swaps recognized in discontinued operations on the statement of income		$ (72)
Gain (loss), after-tax, on interest rate swaps recognized in discontinued operations on the statement of income		$ (42)
Deferred income tax recorded as result of agreement to adjust valuation allowances																								50
Continuing Involvement (Details) [Abstract]
Maximum period for Transition Service Agreement (in years)		2 years
Amount for services billed to spinoff																							$ 25
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Results of Discontinued Operations (Details) [Abstract]
Operating revenues																							1,427	3,848	4,648
Operating expenses																							1,328	3,410	4,173
Other Income (Expense) - net																							(21)	13	32
Interest expense	[5]																						150	190	228
Gain on sale of Montana																							0	237	0
Loss on lease termination																							0	0	0
Income tax expense (benefit)																							(30)	198	(180)
Gain (loss) on disposal group										$ 879													(879)	0	0
Income (Loss) from Discontinued Operations																							$ (921)	300	(238)
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Assets and Liabilities of Discontinued Operations (Details) [Abstract]
Cash and cash equivalents	[6]													352										352		371
Restricted cash and cash equivalents														176										176		156
Accounts receivable and unbilled revenues														504										504		334
Fuels, materials and supplies														455										455		415
Price risk management assets														1,079										1,079		784
Other current assets														26										26		46
Total Current Assets														2,592										2,592		2,106
Investments														980										980		999
Property, plant and equipment, net														6,428										6,428		6,384
Goodwill														338										338		338
Other intangibles														257										257		260
Price risk management assets														239										239		244
Other noncurrent assets														69										69		63
Total Noncurrent Assets														8,311										8,311		8,288
Total assets														10,903										10,903		10,394
Short-term debt and long-term debt due within one year														1,165										1,165		885
Accounts payable														361										361		252
Price risk management liabilities														1,024										1,024		763
Other current liabilities														221										221		229
Total Current Liabilities														2,771										2,771		2,129
Long-term debt (excluding current portion)														1,677										1,677		1,917
Deferred income taxes														1,219										1,219		1,246
Price risk management liabilities														193										193		206
Accrued pension obligations														299										299		266
Asset retirement obligations														415										415		443
Other deferred credits and noncurrent liabilities														150										150		103
Total Noncurrent Liabilities														3,953										3,953		4,181
Total liabilities														6,724										6,724		6,310
Adjustment for loss on spinoff																										879
Net assets distributed																										3,205
PPL Energy Supply Spinoff [Member] | Talen Energy Marketing [Member]
Continuing Involvement (Details) [Abstract]
Energy purchases																						27
PPL Energy Supply Spinoff [Member] | Talen Energy Market Value [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Weighting		50.00%
Weighted fair value																										1,400
Midpoint of premiums received in market sales transactions reviewed		25.00%
Control Premium		25.00%
Review period used in determing the control premium (in years)		5 years
Minimum transaction value reviewed in determining the control premium		$ 1,000
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Assets and Liabilities of Discontinued Operations (Details) [Abstract]
Net assets distributed																										1,400
PPL Energy Supply Spinoff [Member] | Talen Energy Market Value [Member] | Minimum [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Control Premium		5.00%
PPL Energy Supply Spinoff [Member] | Talen Energy Market Value [Member] | Maximum [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Control Premium		42.00%
PPL Energy Supply Spinoff [Member] | Income Discounted Cash Flow [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Weighting		30.00%
Weighted fair value																										1,100
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Assets and Liabilities of Discontinued Operations (Details) [Abstract]
Net assets distributed																										1,100
PPL Energy Supply Spinoff [Member] | Alternative Market Comparable Company [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Weighting		20.00%
Weighted fair value																										700
Midpoint of premiums received in market sales transactions reviewed		25.00%
Control Premium		25.00%
Review period used in determing the control premium (in years)		5 years
Minimum transaction value reviewed in determining the control premium		$ 1,000
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Assets and Liabilities of Discontinued Operations (Details) [Abstract]
Net assets distributed																										$ 700
PPL Energy Supply Spinoff [Member] | Alternative Market Comparable Company [Member] | Minimum [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Control Premium		5.00%
PPL Energy Supply Spinoff [Member] | Alternative Market Comparable Company [Member] | Maximum [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Control Premium		42.00%
Montana Hydroelectric Generating Facilities [Member]
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Results of Discontinued Operations (Details) [Abstract]
Gain (loss) on disposal group				$ 137										137
Divestitures - Montana Hydro Sale (Numeric) [Abstract]
Capacity of facilities sold (in MW) | MW				633
Agreed upon sales price for disposal of hydroelectric facilities owned by PPL Montana				$ 900
Number of hydroelectric facilities owned by PPL Montana sold | Integer				11
Payment on lease termination					$ 271
Loss on sale-leaseback termination, after-tax					$ 413
LGE [Member]
Development Projects [Abstract]
Generating units retired at the Cane Run plant | Integer			1							2
Costs associated with the retirement of generating units								$ 11
LGE [Member] | Solar Generation Facility [Member]
Development Projects [Abstract]
Planned capacity expansion (in MW) | MW																							10
Expected capital cost of an expansion project						30																30	$ 30
KU [Member]
Development Projects [Abstract]
Generating units retired at the Green River plant | Integer								2
Costs associated with the retirement of generating units								$ 6
KU [Member] | Solar Generation Facility [Member]
Development Projects [Abstract]
Planned capacity expansion (in MW) | MW																							10
Expected capital cost of an expansion project						30																30	$ 30
PPL Electric Utilities Corp [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Deferred income tax recorded as result of agreement to adjust valuation allowances																							220	87	127
Continuing Involvement (Details) [Abstract]
Energy purchases																							657	587	588
Development Projects [Abstract]
Construction work in progress						530								738								530	$ 530	738
PPL Electric Utilities Corp [Member] | Susquehanna Roseland Transmission Line [Member]
Development Projects [Abstract]
Total length (in miles) of the expansion project | mi																							150
Capacity (in kilovolts) of a transmission line | kV																							500
Project costs capitalized						$ 648								597								$ 648	$ 648	597
PPL Electric Utilities Corp [Member] | Northeast Pocono Reliability Project [Member]
Development Projects [Abstract]
Total length (in miles) of the expansion project | mi																							58
Capacity (in kilovolts) of a transmission line | kV																							230
Adder to the return on equity incentive denied in ratemaking request (in basis points) | Integer						100																100	100
Expected capital cost of an expansion project						$ 335																$ 335	$ 335
Number of new substations included in request | Integer						3																3	3
Capitalized costs						$ 319								183								$ 319	$ 319	183
PPL Electric Utilities Corp [Member] | PPL Energy Supply Spinoff [Member] | Talen Energy Marketing [Member]
Continuing Involvement (Details) [Abstract]
Energy purchases																						27
LG And E And KU Energy LLC [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Deferred income tax recorded as result of agreement to adjust valuation allowances																							236	449	254
Continuing Involvement (Details) [Abstract]
Energy purchases																							184	253	217
Discontinued Operations - Spinoff of PPL Energy Supply - Summarized Results of Discontinued Operations (Details) [Abstract]
Income tax expense (benefit)																							0	0	1
Income (Loss) from Discontinued Operations																							0	0	2
Development Projects [Abstract]
Construction work in progress						660								1,559								660	$ 660	1,559
LG And E And KU Energy LLC [Member] | LGE [Member]
Development Projects [Abstract]
Generating units retired at the Cane Run plant | Integer			1							2
Costs associated with the retirement of generating units								$ 11
LG And E And KU Energy LLC [Member] | LGE [Member] | Solar Generation Facility [Member]
Development Projects [Abstract]
Planned capacity expansion (in MW) | MW																							10
Expected capital cost of an expansion project						30																30	$ 30
LG And E And KU Energy LLC [Member] | KU [Member]
Development Projects [Abstract]
Generating units retired at the Green River plant | Integer								2
Costs associated with the retirement of generating units								$ 6
LG And E And KU Energy LLC [Member] | KU [Member] | Solar Generation Facility [Member]
Development Projects [Abstract]
Planned capacity expansion (in MW) | MW																							10
Expected capital cost of an expansion project						30																30	$ 30
Louisville Gas And Electric Co [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Deferred income tax recorded as result of agreement to adjust valuation allowances																							126	118	26
Continuing Involvement (Details) [Abstract]
Energy purchases																							166	230	195
Development Projects [Abstract]
Generating units retired at the Cane Run plant | Integer			1							2
Costs associated with the retirement of generating units								$ 11
Construction work in progress						390								676								390	$ 390	676
Louisville Gas And Electric Co [Member] | Solar Generation Facility [Member]
Development Projects [Abstract]
Planned capacity expansion (in MW) | MW																							10
Expected capital cost of an expansion project						30																30	$ 30
Kentucky Utilities Co [Member]
Discontinued Operations - Spinoff of PPL Energy Supply (Numeric) [Abstract]
Deferred income tax recorded as result of agreement to adjust valuation allowances																							160	224	69
Continuing Involvement (Details) [Abstract]
Energy purchases																							18	23	$ 22
Development Projects [Abstract]
Generating units retired at the Green River plant | Integer								2
Costs associated with the retirement of generating units								$ 6
Construction work in progress						267								$ 880								267	$ 267	$ 880
Kentucky Utilities Co [Member] | Solar Generation Facility [Member]
Development Projects [Abstract]
Planned capacity expansion (in MW) | MW																							10
Expected capital cost of an expansion project						$ 30																$ 30	$ 30
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.
[2]	In the second quarter of 2015, PPL completed the spinoff of PPL Energy Supply sub stantially representing PPL's Supply segment. Accordingly, the previously reported operating results for PPL’s Supply segment have been reclassified as discontinued operations. See Note 8 to the Financial Statements for additional information.
[3]	The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information.
[4]	(f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
[5]	Includes interest associated with the Supply segment with no additional allocation as the Supply segment was sufficiently capitalized.
[6]	The distribution of PPL Energy Supply’s cash and cash equivalents at June 1, 2015 is included in "Net cash provided by (used in) financing activities - discontinued operations" on the Statement of Cash Flows for the year ended December 31, 2015 .

Leases (Details)

Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Rent - Operating Leases (Details) [Abstract]
Operating leases, rent expense	$ 49	$ 51	$ 56
Operating leases, future minimum rental payments due (Details) [Abstract]
2,016	33
2,017	28
2,018	24
2,019	14
2,020	11
Thereafter	31
Total	141
LG And E And KU Energy LLC [Member]
Rent - Operating Leases (Details) [Abstract]
Operating leases, rent expense	24	18	18
Operating leases, future minimum rental payments due (Details) [Abstract]
2,016	25
2,017	23
2,018	21
2,019	12
2,020	9
Thereafter	22
Total	112
Louisville Gas And Electric Co [Member]
Rent - Operating Leases (Details) [Abstract]
Operating leases, rent expense	12	7	7
Operating leases, future minimum rental payments due (Details) [Abstract]
2,016	14
2,017	14
2,018	13
2,019	7
2,020	4
Thereafter	10
Total	62
Kentucky Utilities Co [Member]
Rent - Operating Leases (Details) [Abstract]
Operating leases, rent expense	11	$ 10	$ 10
Operating leases, future minimum rental payments due (Details) [Abstract]
2,016	10
2,017	9
2,018	7
2,019	5
2,020	5
Thereafter	11
Total	$ 47

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)		12 Months Ended
		Dec. 31, 2015USD ($)Integer$ / sharesshares	Dec. 31, 2014USD ($)Integer$ / sharesshares	Dec. 31, 2013USD ($)Integer$ / shares
All Awards [Member]
Aggregate disclosures [Abstract]
Unrecognized compensation expense | $		$ 8,000,000
Weighted-average period for recognition | Integer		1.6
All Plans [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Granted (in shares)		90,251
All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)		3,485,520
Granted (in shares)		1,028,009
Anti-dilution adjustments	[1]	247,098
Vested (in shares)		(3,055,205)
Forfeited (in shares)		(25,947)
Nonvested, end of period (in shares)		1,679,475	3,485,520
Awards, other than equity based, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares		$ 30.07
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares		34.5	$ 31.5	$ 30.3
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares		29.34
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares		30.7
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares		$ 29.65	$ 30.07
Total fair value of units vested during the period | $		$ 28,000,000	$ 11,000,000	$ 12,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)		3 years	3 years	3 years
All Plans [Member] | Restricted Shares And Units [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Granted (in shares)		247,098
Vested (in shares)		1,226,193
All Plans [Member] | Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)		1,171,716
Granted (in shares)		481,197
Anti-dilution adjustments	[2]	90,251
Vested (in shares)		(509,139)
Forfeited (in shares)		240,485
Nonvested, end of period (in shares)		993,540	1,171,716
Awards, other than equity based, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares		$ 33.77
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares		36.76	$ 34.55	$ 34.15
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares		32.12
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares		33.35
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares		$ 33.09	$ 33.77
Total fair value of units vested during the period | $		$ 6,000,000	$ 5,000,000
Period over which performance units fair value is recognized (in years)				3 years
Maximum payout percentage of target award		200.00%
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)		3 years	3 years	3 years
Risk-free interest rate		0.75%	0.75%	0.36%
Expected option life (in years) | Integer		3	3	3
Expected stock volatility		15.90%	15.80%	15.50%
All Plans [Member] | Performance Units [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Vested (in shares)		322,429
All Plans [Member] | Performance Units [Member] | Retirement Eligible [Member]
Awards, other than equity based, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)		1 year	1 year
All Plans [Member] | Performance Units [Member] | Not Retirement Eligible [Member]
Awards, other than equity based, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)		3 years	3 years
Aggregate disclosures [Abstract]
Minimum period after which employee stock options become exercisable (in years)		1 year	1 year
All Plans [Member] | Stock Options [Member]
Aggregate disclosures [Abstract]
Cash received from exercise of stock options | $		$ 97,000,000	$ 67,000,000	$ 31,000,000
Minimum period after which employee stock options become exercisable (in years)		1 year
Fair value assumptions and methodology [Abstract]
Risk-free interest rate			1.15%
Expected option life (in years) | Integer				6.48
Expected stock volatility			18.50%
Dividend yield				5.00%
Stock option activity [Roll Forward]
Outstanding at beginning of period (in shares)		9,042,962
Anti-dilution adjustments	[3]	907,737
Exercised (in shares)		(3,559,874)
Forfeited (in shares)		(5,676)
Outstanding at end of period (in shares)		6,385,149	9,042,962
Stock options - additional disclosures [Abstract]
Percentage of total of long-term incentive mix from performance units		60.00%
Percentage of total of long-term incentive mix from performance-contingent restricted stock units		40.00%
Total percentage of performance-based long-term incentive mix that are equity awards		100.00%
Period that performance goals are evaluated (in years)		3 years
Period after which, employee stock options expire (in years)		10 years
Weighted-average exercise price per share at beginning of period (in dollars per share) | $ / shares		$ 30.93
Weighted average exercise price per share, anti-dilution adjustments (in dollars per share) | $ / shares		28.06
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares		27.35
Weighted average exercise price per share, forfeited (in dollars per share) | $ / shares		26.67
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares		$ 28.54	$ 30.93
Weighted average remaining contractual term (in years) | Integer		5.2
Aggregate total intrinsic value | $		$ 42,000,000
Options exercisable at end of period (in shares)		5,683,535
Weighted average exercise price, options exercisable at end of period (in dollars per share) | $ / shares		$ 28.78
Weighted average remaining contractual term, options exercisable at end of period (in years) | Integer		5
Aggregate total intrinsic value, options exercisable at end of period | $		$ 36,000,000
Weighted average grant date fair value of options granted (in dollars per share) | $ / shares				$ 2.18
Total intrinsic value of stock options exercised | $		21,000,000	$ 13,000,000	$ 6,000,000
All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $		33,000,000	30,000,000	25,000,000
Income tax benefit | $		$ 14,000,000	$ 12,000,000	$ 11,000,000
Incentive Compensation Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	[4]	15,769,431
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	[4]	2.00%
Annual grant limit options (in shares)	[4]	3,000,000
Annual grant limit for individual participants - performance based awards (in shares)		0
Annual grant limit for individual participants - performance based awards | $		$ 0
Incentive Compensation Plan [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after the date of grant that employee must be employed before stock option exercise date can be accelerated (in years)		1 year
Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Period after grant, employee stock options expire upon retirement (in years)		10 years
Period after which, employee stock options expire upon retirement (in years)		5 years
Maximum number of shares approved for awards under the plan (in shares)		10,000,000
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year		0.00%
Annual grant limit options (in shares)		2,000,000
Annual grant limit for individual participants - performance based awards (in shares)		750,000
Annual grant limit for individual participants - performance based awards | $		$ 15,000,000
Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)		14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year		2.00%
Annual grant limit options (in shares)		3,000,000
Annual grant limit for individual participants - performance based awards (in shares)		0
Annual grant limit for individual participants - performance based awards | $		$ 0
PPL Electric Utilities Corp [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Unrecognized compensation expense | $		$ 2,000,000
Weighted-average period for recognition | Integer		1.6
PPL Electric Utilities Corp [Member] | All Plans [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Granted (in shares)		4,627
PPL Electric Utilities Corp [Member] | All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)		286,811
Transfer between registrants		(22,730)
Granted (in shares)		75,213
Anti-dilution adjustments	[1]	18,661
Vested (in shares)		(127,507)
Forfeited (in shares)		(9,363)
Nonvested, end of period (in shares)		221,085	286,811
Awards, other than equity based, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares		$ 30.04
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares		29.56
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares		34.41	$ 31.81	$ 30.55
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares		29.12
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares		30.51
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares		$ 29.48	$ 30.04
Total fair value of units vested during the period | $		$ 4,000,000	$ 2,000,000	$ 3,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)		3 years	3 years	3 years
PPL Electric Utilities Corp [Member] | All Plans [Member] | Restricted Shares And Units [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Granted (in shares)		18,661
PPL Electric Utilities Corp [Member] | All Plans [Member] | Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)		59,615
Transfer between registrants		(3,676)
Granted (in shares)		21,798
Anti-dilution adjustments	[2]	4,627
Vested (in shares)		(8,497)
Forfeited (in shares)		6,196
Nonvested, end of period (in shares)		67,671	59,615
Awards, other than equity based, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares		$ 33.77
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares		35.8
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares		37.93	$ 34.43	$ 33.97
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares		31.38
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares		31.38
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares		$ 33.05	$ 33.77
Period over which performance units fair value is recognized (in years)				3 years
Maximum payout percentage of target award		200.00%
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)		3 years	3 years	3 years
Risk-free interest rate		0.75%	0.75%	0.36%
Expected option life (in years) | Integer		3	3	3
Expected stock volatility		15.90%	15.80%	15.50%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Performance Units [Member] | Retirement Eligible [Member]
Awards, other than equity based, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)		1 year	1 year
PPL Electric Utilities Corp [Member] | All Plans [Member] | Performance Units [Member] | Not Retirement Eligible [Member]
Awards, other than equity based, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)		3 years	3 years
Aggregate disclosures [Abstract]
Minimum period after which employee stock options become exercisable (in years)		1 year	1 year
PPL Electric Utilities Corp [Member] | All Plans [Member] | Stock Options [Member]
Aggregate disclosures [Abstract]
Minimum period after which employee stock options become exercisable (in years)		1 year
Fair value assumptions and methodology [Abstract]
Risk-free interest rate			1.15%
Expected option life (in years) | Integer			6.48
Expected stock volatility			18.50%
Dividend yield				5.00%
Stock option activity [Roll Forward]
Outstanding at beginning of period (in shares)		507,920
Transferred (in shares)		15,339
Transfer between registrants		(15,339)
Anti-dilution adjustments	[3]	44,859
Exercised (in shares)		(224,007)
Outstanding at end of period (in shares)		313,433	507,920
Stock options - additional disclosures [Abstract]
Percentage of total of long-term incentive mix from performance units		60.00%
Percentage of total of long-term incentive mix from performance-contingent restricted stock units		40.00%
Total percentage of performance-based long-term incentive mix that are equity awards		100.00%
Period that performance goals are evaluated (in years)		3 years
Period after which, employee stock options expire (in years)		10 years
Weighted-average exercise price per share at beginning of period (in dollars per share) | $ / shares		$ 30.04
Weighted average exercise price per share, transfer between registrants (in dollars per share) | $ / shares		29.6
Weighted average exercise price per share, anti-dilution adjustments (in dollars per share) | $ / shares		28.06
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares		27.2
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares		$ 27.79	$ 30.04
Weighted average remaining contractual term (in years) | Integer		5.2
Aggregate total intrinsic value | $		$ 2,000,000
Options exercisable at end of period (in shares)		263,443
Weighted average exercise price, options exercisable at end of period (in dollars per share) | $ / shares		$ 28.02
Weighted average remaining contractual term, options exercisable at end of period (in years) | Integer		4.8
Aggregate total intrinsic value, options exercisable at end of period | $		$ 2,000,000
Weighted average grant date fair value of options granted (in dollars per share) | $ / shares				$ 2.19
PPL Electric Utilities Corp [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $		14,000,000	$ 12,000,000	$ 10,000,000
Income tax benefit | $		$ 6,000,000	$ 5,000,000	$ 4,000,000
PPL Electric Utilities Corp [Member] | Incentive Compensation Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	[4]	15,769,431
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	[4]	2.00%
Annual grant limit options (in shares)	[4]	3,000,000
Annual grant limit for individual participants - performance based awards (in shares)		0
Annual grant limit for individual participants - performance based awards | $		$ 0
PPL Electric Utilities Corp [Member] | Incentive Compensation Plan [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after the date of grant that employee must be employed before stock option exercise date can be accelerated (in years)		1 year
PPL Electric Utilities Corp [Member] | Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Period after grant, employee stock options expire upon retirement (in years)		10 years
Period after which, employee stock options expire upon retirement (in years)		5 years
Maximum number of shares approved for awards under the plan (in shares)		10,000,000
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year		0.00%
Annual grant limit options (in shares)		2,000,000
Annual grant limit for individual participants - performance based awards (in shares)		750,000
Annual grant limit for individual participants - performance based awards | $		$ 15,000,000
PPL Electric Utilities Corp [Member] | Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)		14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year		2.00%
Annual grant limit options (in shares)		3,000,000
Annual grant limit for individual participants - performance based awards (in shares)		0
Annual grant limit for individual participants - performance based awards | $		$ 0
LG And E And KU Energy LLC [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Unrecognized compensation expense | $		$ 1,000,000
Weighted-average period for recognition | Integer		1.4
LG And E And KU Energy LLC [Member] | All Plans [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Granted (in shares)		13,207
LG And E And KU Energy LLC [Member] | All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)		341,468
Transfer between registrants		4,300
Granted (in shares)		98,360
Anti-dilution adjustments	[1]	24,587
Vested (in shares)		(149,752)
Nonvested, end of period (in shares)		318,963	341,468
Awards, other than equity based, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares		$ 29.76
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares		31.74
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares		34.89	$ 30.98	$ 30
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares		28.55
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares		$ 29.65	$ 29.76
Total fair value of units vested during the period | $		$ 4,000,000	$ 0	$ 1,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)		3 years	3 years	3 years
LG And E And KU Energy LLC [Member] | All Plans [Member] | Restricted Shares And Units [Member] | PPL Energy Supply Spinoff [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Granted (in shares)		24,587
LG And E And KU Energy LLC [Member] | All Plans [Member] | Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)		173,946
Granted (in shares)		66,439
Anti-dilution adjustments	[2]	13,207
Vested (in shares)		(30,921)
Forfeited (in shares)		29,507
Nonvested, end of period (in shares)		193,164	173,946
Awards, other than equity based, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares		$ 33.32
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares		37.1	$ 34.12	$ 33.84
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares		31.35
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares		31.36
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares		$ 32.96	$ 33.32
Period over which performance units fair value is recognized (in years)				3 years
Maximum payout percentage of target award		200.00%
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)		3 years	3 years	3 years
Risk-free interest rate		0.75%	0.75%	0.36%
Expected option life (in years) | Integer		3	3	3
Expected stock volatility		15.90%	15.80%	15.50%
LG And E And KU Energy LLC [Member] | All Plans [Member] | Performance Units [Member] | Retirement Eligible [Member]
Awards, other than equity based, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)		1 year	1 year
LG And E And KU Energy LLC [Member] | All Plans [Member] | Performance Units [Member] | Not Retirement Eligible [Member]
Awards, other than equity based, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)		3 years	3 years
Aggregate disclosures [Abstract]
Minimum period after which employee stock options become exercisable (in years)		1 year	1 year
LG And E And KU Energy LLC [Member] | All Plans [Member] | Stock Options [Member]
Aggregate disclosures [Abstract]
Minimum period after which employee stock options become exercisable (in years)		1 year
Fair value assumptions and methodology [Abstract]
Risk-free interest rate				1.15%
Expected option life (in years) | Integer				6.48
Expected stock volatility			18.50%
Dividend yield				5.00%
Stock option activity [Roll Forward]
Outstanding at beginning of period (in shares)		623,317
Transfer between registrants		0
Anti-dilution adjustments	[3]	43,236
Exercised (in shares)		(240,897)
Outstanding at end of period (in shares)		425,656	623,317
Stock options - additional disclosures [Abstract]
Percentage of total of long-term incentive mix from performance units		60.00%
Percentage of total of long-term incentive mix from performance-contingent restricted stock units		40.00%
Total percentage of performance-based long-term incentive mix that are equity awards		100.00%
Period that performance goals are evaluated (in years)		3 years
Period after which, employee stock options expire (in years)		10 years
Weighted-average exercise price per share at beginning of period (in dollars per share) | $ / shares		$ 28.64
Weighted average exercise price per share, transfer between registrants (in dollars per share) | $ / shares		0
Weighted average exercise price per share, anti-dilution adjustments (in dollars per share) | $ / shares		28.06
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares		28.04
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares		$ 26.08	$ 28.64
Weighted average remaining contractual term (in years) | Integer		6.7
Aggregate total intrinsic value | $		$ 3,000,000
Options exercisable at end of period (in shares)		277,101
Weighted average exercise price, options exercisable at end of period (in dollars per share) | $ / shares		$ 25.8
Weighted average remaining contractual term, options exercisable at end of period (in years) | Integer		6.5
Aggregate total intrinsic value, options exercisable at end of period | $		$ 2,000,000
Weighted average grant date fair value of options granted (in dollars per share) | $ / shares				$ 2.18
LG And E And KU Energy LLC [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $		8,000,000	$ 8,000,000	$ 8,000,000
Income tax benefit | $		$ 3,000,000	$ 3,000,000	$ 3,000,000
LG And E And KU Energy LLC [Member] | Incentive Compensation Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	[4]	15,769,431
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	[4]	2.00%
Annual grant limit options (in shares)	[4]	3,000,000
Annual grant limit for individual participants - performance based awards (in shares)		0
Annual grant limit for individual participants - performance based awards | $		$ 0
LG And E And KU Energy LLC [Member] | Incentive Compensation Plan [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after the date of grant that employee must be employed before stock option exercise date can be accelerated (in years)		1 year
LG And E And KU Energy LLC [Member] | Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Period after grant, employee stock options expire upon retirement (in years)		10 years
Period after which, employee stock options expire upon retirement (in years)		5 years
Maximum number of shares approved for awards under the plan (in shares)		10,000,000
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year		0.00%
Annual grant limit options (in shares)		2,000,000
Annual grant limit for individual participants - performance based awards (in shares)		750,000
Annual grant limit for individual participants - performance based awards | $		$ 15,000,000
LG And E And KU Energy LLC [Member] | Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)		14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year		2.00%
Annual grant limit options (in shares)		3,000,000
Annual grant limit for individual participants - performance based awards (in shares)		0
Annual grant limit for individual participants - performance based awards | $		$ 0
[1]	Includes adjustment to all restricted stock units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock-based compensation Plans.
[2]	Includes adjustment to all performance units granted prior to the spinoff of PPL Energy Supply as provided for under the anti-dilution provisions of PPL’s stock - based compensation P lans.
[3]	Adjustments to prior year grants under the anti-dilution provisions of PPL’s stock - based compensation Plans as a result of the spinoff of PPL Energy Supply .
[4]	Applicable to outstanding awards granted from January 27, 2006 to January 26, 2012. During 2012, the total plan award limit was reached and the ICP was replaced by the SIP.

Retirement and Postemployment76

Retirement and Postemployment Benefits (Net Period Defined Benefit Costs (Credits) and Other Changes in Plan Assets and Benefit Obligations) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		$ 96		$ 97		$ 119
Interest cost		194		224		205
Expected return on plan assets		(258)		(287)		(283)
Amortization of:
Prior service cost (credits)		7		20		22
Actuarial (gain) loss		84		28		77
Net periodic defined benefit costs (credits) prior to settlement charges, curtailment charges (credits) and termination benefits		123		82		140
Termination benefits		0		13		0
Net periodic defined benefit costs (credits)		123		95		140
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Divestiture		(353)	[1]	0		0
Net (gain) loss		63		574		(304)
Prior service costs (credit)		18		(8)		0
Amortization of: [Abstract]
Prior service (cost) credit		(7)		(20)		(22)
Actuarial gain (loss)		(85)		(28)		(77)
Acquisition of regulatory assets/liabilities: [Abstract]
Total recognized in OCI and regulatory assets/liabilities		(364)		518		(403)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities		(241)		613		(263)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI		(269)		319		(210)
Regulatory assets/liabilities		(95)		199		(193)
Total recognized in OCI and regulatory assets/liabilities		(364)		518		(403)
Estimated Amounts to be Amortized From AOCI and Regulatory Assets into Net Periodic Benefit Costs in the Next Fiscal Period (Details) [Abstract]
Prior service cost (credit)		8
Actuarial (gain) loss		49
Total		57
Amortization from Balance Sheet: [Abstract]
AOCI		12
Regulatory assets/liabilities		45
Total		57
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		$ 71		45		72
Amortization period for the deferred recovery of a regulatory asset		15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 4
Pension Benefits United Kingdom [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		79		71		69
Interest cost		314		354		320
Expected return on plan assets		(523)		(521)		(465)
Amortization of:
Prior service cost (credits)		0		0		1
Actuarial (gain) loss		158		132		150
Net periodic defined benefit costs (credits) prior to settlement charges, curtailment charges (credits) and termination benefits		28		36		75
Termination benefits		0		0		3
Net periodic defined benefit costs (credits)		28		36		78
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss		508		354		76
Prior service costs (credit)		0		0		0
Amortization of: [Abstract]
Prior service (cost) credit		0		0		(1)
Actuarial gain (loss)		(158)		(132)		(150)
Acquisition of regulatory assets/liabilities: [Abstract]
Total recognized in OCI and regulatory assets/liabilities	[2]	350		222		(75)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	[2]	378		258		3
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
Total recognized in OCI and regulatory assets/liabilities	[2]	350		222		(75)
Estimated Amounts to be Amortized From AOCI and Regulatory Assets into Net Periodic Benefit Costs in the Next Fiscal Period (Details) [Abstract]
Prior service cost (credit)		0
Actuarial (gain) loss		151
Total		151
Amortization from Balance Sheet: [Abstract]
AOCI		151
Regulatory assets/liabilities		0
Total		151
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		(21)		(9)		33
Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		11		12		13
Interest cost		26		31		29
Expected return on plan assets		(26)		(26)		(25)
Amortization of:
Prior service cost (credits)		1		0		0
Actuarial (gain) loss		0		1		6
Net periodic defined benefit costs (credits) prior to settlement charges, curtailment charges (credits) and termination benefits		12		18		23
Termination benefits		0		0		0
Net periodic defined benefit costs (credits)		12		18		23
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Divestiture		(6)	[1]	0		0
Net (gain) loss		(9)		22		(67)
Prior service costs (credit)		0		7		0
Amortization of: [Abstract]
Prior service (cost) credit		(1)		0		0
Actuarial gain (loss)		0		(1)		(6)
Acquisition of regulatory assets/liabilities: [Abstract]
Total recognized in OCI and regulatory assets/liabilities		(16)		28		(73)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities		(4)		46		(50)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI		12		7		(37)
Regulatory assets/liabilities		(28)		21		(36)
Total recognized in OCI and regulatory assets/liabilities		(16)		28		(73)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		8		10		13
PPL Electric Utilities Corp [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	[3]	15		12		18
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		0		2	[3]	3	[3]
LG And E And KU Energy LLC [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		(9)
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		26		21		26
Interest cost		68		66		62
Expected return on plan assets		(88)		(82)		(82)
Amortization of:
Prior service cost (credits)		7		5		5
Actuarial (gain) loss		37	[4]	12		33
Net periodic defined benefit costs (credits)		50		22		44
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss		20		162		(116)
Prior service costs (credit)		19		23		0
Amortization of: [Abstract]
Prior service (cost) credit		(7)		(5)		(5)
Actuarial gain (loss)		(37)		(12)		(33)
Acquisition of regulatory assets/liabilities: [Abstract]
Total recognized in OCI and regulatory assets/liabilities		(5)		168		(154)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities		45		190		(110)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI		4		84		(46)
Regulatory assets/liabilities		(9)		84		(108)
Total recognized in OCI and regulatory assets/liabilities		(5)		168		(154)
Estimated Amounts to be Amortized From AOCI and Regulatory Assets into Net Periodic Benefit Costs in the Next Fiscal Period (Details) [Abstract]
Prior service cost (credit)		8
Actuarial (gain) loss		20
Total		28
Amortization from Balance Sheet: [Abstract]
AOCI		2
Regulatory assets/liabilities		26
Total		28
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		$ 37	[5]	17		32
Amortization period for the deferred recovery of a regulatory asset		15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 4
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		5		4		5
Interest cost		9		9		8
Expected return on plan assets		(6)		(4)		(5)
Amortization of:
Prior service cost (credits)		3		2		3
Actuarial (gain) loss		0		(1)		0
Net periodic defined benefit costs (credits)		11		10		11
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss		(15)		26		(14)
Prior service costs (credit)		0		6		0
Amortization of: [Abstract]
Prior service (cost) credit		(3)		(2)		(3)
Actuarial gain (loss)		0		1		0
Acquisition of regulatory assets/liabilities: [Abstract]
Total recognized in OCI and regulatory assets/liabilities		(18)		31		(17)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities		(7)		41		(6)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI		(2)		9		(1)
Regulatory assets/liabilities		(16)		22		(16)
Total recognized in OCI and regulatory assets/liabilities		(18)		31		(17)
Estimated Amounts to be Amortized From AOCI and Regulatory Assets into Net Periodic Benefit Costs in the Next Fiscal Period (Details) [Abstract]
Prior service cost (credit)		2
Actuarial (gain) loss		0
Total		2
Amortization from Balance Sheet: [Abstract]
AOCI		1
Regulatory assets/liabilities		1
Total		2
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		8		7		8
Louisville Gas And Electric Co [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		(3)
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		1		1		2
Interest cost		14		15		14
Expected return on plan assets		(20)		(19)		(20)
Amortization of:
Prior service cost (credits)		3		2		2
Actuarial (gain) loss		11	[6]	6		14
Net periodic defined benefit costs (credits)		9		5		12
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss		8		14		(20)
Prior service costs (credit)		10		9		0
Amortization of: [Abstract]
Prior service (cost) credit		(3)		(2)		(2)
Actuarial gain (loss)		(11)		(6)		(14)
Acquisition of regulatory assets/liabilities: [Abstract]
Total recognized in OCI and regulatory assets/liabilities		4		15		(36)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities		13		20		(24)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
Total recognized in OCI and regulatory assets/liabilities		4		15		(36)
Estimated Amounts to be Amortized From AOCI and Regulatory Assets into Net Periodic Benefit Costs in the Next Fiscal Period (Details) [Abstract]
Prior service cost (credit)		5
Actuarial (gain) loss		7
Total		12
Amortization from Balance Sheet: [Abstract]
Total		12
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		$ 12	[5]	5		14
Amortization period for the deferred recovery of a regulatory asset		15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 4
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors		5		2		5
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		4		4		4
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits United States [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors		4		4		4
Kentucky Utilities Co [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	[3]	$ 9	[5]	3		9
Amortization period for the deferred recovery of a regulatory asset		15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 1
Kentucky Utilities Co [Member] | Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	[3]	$ 2		$ 2		$ 2
[1]	As a result of the spinoff of PPL Energy Supply, amounts in AOCI were allocated to certain former active and inactive employees of PPL Energy Supply and included in the distribution . See Note 8 for additional details.
[2]	WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. As a result, WPD does not record regulatory assets/liabilities.
[3]	PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable.
[4]	As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LKE’s pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $ 9 million.
[5]	As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between net periodic defined benefit costs calculated in acco rdance with LKE’s, LG&E’s and KU’s pension accounting policy and the net periodic defined benefit costs calculated using a 15 year amortization period for gains and losses is recorded as a regulatory asset. Of the costs charge d to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts, $ 4 million for LG&E and $ 1 million for KU were recorded as regulatory assets.
[6]	As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E’s pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $ 3 million.

Retirement and Postemployment77

Retirement and Postemployment Benefits (Weighted-Average Assumptions, Cost Trend Rates and Funded Status) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent liabilities of discontinued operations		$ 0		$ (3,953)
Pension Benefits United States [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate		4.59%		4.25%
Benefit obligations valuation rate of compensation increase		3.93%		3.91%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		4.25%		5.12%		4.22%
Net periodic benefit costs rate of compensation increase		3.91%		3.97%		3.98%
Net periodic benefit costs expected return on plan assets	[1]	7.00%		7.00%		7.03%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations		6.80%		7.20%		7.60%
Health care cost trend rate assumed for next year, cost		7.20%		7.60%		8.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), obligations		5.00%		5.00%		5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate),cost		5.00%		5.00%		5.50%
Year that the rate reaches the ultimate trend rate, obligations		2,020		2,020		2,020
Year that the rate reaches the ultimate trend rate, cost		2,020		2,020		2,019
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 5,399		$ 4,428
Service cost		96		97		$ 119
Interest cost		194		224		205
Participant contributions		0		0
Plan amendments		19		(7)
Actuarial (gain) loss		(193)		887
Divestiture		(1,416)	[2]	0
Termination benefits		0		13
Gross benefits paid		(236)		(243)	[3]
Currency conversion		0		0
Benefit Obligation, end of period		3,863		5,399		4,428
Change in Plan Assets [Roll Forward]
Balance at beginning of period		4,462		4,009
Actual return on plan assets		2		600
Employer contributions		158		96
Participant contributions		0		0
Divestiture		(1,159)	[2]	0
Gross benefits paid		(236)		(243)	[3]
Currency conversion		0		0
Balance at end of period		3,227		4,462		$ 4,009
Funded Status, end of period		(636)		(937)
Lump sum cash payouts made to terminated vested employees		33
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset		0		0
Current liability		(10)		(10)
Noncurrent liability		(626)		(668)
Noncurrent liabilities of discontinued operations		0		(259)
Net amount recognized, end of period		(636)		(937)
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)		53		41
Net actuarial (gain) loss		977		1,353
Total		1,030		1,394
Total accumulated benefit obligation for defined benefit pension plans		3,590		4,946
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI		275		714
Regulatory assets/liabilities		755		680
Total		1,030		1,394
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Value of Plan Assets (Details) [Abstract]
Projected benefit obligations		3,863		5,399
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets		3,227		4,462
Accumulated benefit obligation		3,590		4,946
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets		$ 3,227		$ 4,462
Pension Benefits United Kingdom [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate		3.68%		3.85%
Benefit obligations valuation rate of compensation increase		4.00%		4.00%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		3.85%		4.41%		4.27%
Net periodic benefit costs rate of compensation increase		4.00%		4.00%		4.00%
Net periodic benefit costs expected return on plan assets	[1]	7.19%		7.19%		7.16%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 8,523		$ 8,143
Service cost		79		71		$ 69
Interest cost		314		354		320
Participant contributions		15		16
Plan amendments		0		0
Actuarial (gain) loss		200		747
Divestiture		0		0
Termination benefits		0		0
Gross benefits paid		(391)		(411)
Currency conversion		(336)		(397)
Benefit Obligation, end of period		8,404		8,523		8,143
Change in Plan Assets [Roll Forward]
Balance at beginning of period		7,734		7,284
Actual return on plan assets		205		895
Employer contributions		366		311
Participant contributions		15		16
Divestiture		0		0
Gross benefits paid		(391)		(411)
Currency conversion		(304)		(361)
Balance at end of period		7,625		7,734		$ 7,284
Funded Status, end of period		(779)		(789)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset		0		0
Current liability		0		(1)
Noncurrent liability		(779)		(788)
Net amount recognized, end of period		(779)		(789)
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)		0		0
Net actuarial (gain) loss		2,684		2,334
Total	[4]	2,684		2,334
Total accumulated benefit obligation for defined benefit pension plans		7,747		7,867
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total	[4]	2,684		2,334
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Value of Plan Assets (Details) [Abstract]
Projected benefit obligations		8,404		8,523
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets		7,625		7,734
Accumulated benefit obligation		3,532		3,592
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets		$ 3,287		$ 3,321
Other Postretirement Benefits United States [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate		4.48%		4.09%
Benefit obligations valuation rate of compensation increase		3.91%		3.86%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		4.09%		4.91%		4.00%
Net periodic benefit costs rate of compensation increase		3.86%		3.96%		3.97%
Net periodic benefit costs expected return on plan assets	[1]	6.06%		5.96%		5.94%
Effect of One Percentage Point Change in Assumed Health Care Costs Trend Rate (Details) [Abstract]
Effect on accumulated postretirement benefit obligation of a one percentage point increase		$ 6
Effect on accumulated postretirement benefit obligation of a one percentage point decrease		(5)
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		716		$ 650
Service cost		11		12		$ 13
Interest cost		26		31		29
Participant contributions		13		12
Plan amendments		0		6
Actuarial (gain) loss		(37)		59
Divestiture		(76)	[2]	0
Termination benefits		0		0
Gross benefits paid		(58)		(55)
Federal subsidy		1		1
Currency conversion		0		0
Benefit Obligation, end of period		596		716		650
Change in Plan Assets [Roll Forward]
Balance at beginning of period		484		446
Actual return on plan assets		(2)		62
Employer contributions		17		15
Participant contributions		13		12
Divestiture		(80)	[2]	0
Gross benefits paid		(53)		(51)
Currency conversion		0		0
Balance at end of period		379		484		$ 446
Funded Status, end of period		(217)		(232)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset		2		1
Current liability		(3)		(3)
Noncurrent liability		(216)		(196)
Noncurrent liabilities of discontinued operations		0		(34)
Net amount recognized, end of period		(217)		(232)
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)		1		0
Net actuarial (gain) loss		37		54
Total		38		54
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI		18		30
Regulatory assets/liabilities		20		24
Total		38		54
PPL Electric Utilities Corp [Member]
Change in Plan Assets [Roll Forward]
Non-cash contributions related to remeasurement and separation of benefit plans		56
PPL Electric Utilities Corp [Member] | Pension Benefits United States [Member] | PPL Services Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period		183		212
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits United States [Member] | PPL Services Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period		$ 67		$ 40
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate		4.56%		4.25%
Benefit obligations valuation rate of compensation increase		3.50%		3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		4.25%		5.18%		4.24%
Net periodic benefit costs rate of compensation increase		3.50%		4.00%		4.00%
Net periodic benefit costs expected return on plan assets	[1]	7.00%		7.00%		7.10%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations		6.80%		7.20%		7.60%
Health care cost trend rate assumed for next year, cost		7.20%		7.60%		8.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), obligations		5.00%		5.00%		5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate),cost		5.00%		5.00%		5.50%
Year that the rate reaches the ultimate trend rate, obligations		2,020		2,020		2,020
Year that the rate reaches the ultimate trend rate, cost		2,020		2,020		2,019
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 1,608		$ 1,328
Service cost		26		21		$ 26
Interest cost		68		66		62
Participant contributions		0		0
Plan amendments	[5]	19		23
Actuarial (gain) loss		(74)		253
Gross benefits paid		(59)		(83)	[6]
Benefit Obligation, end of period		1,588		1,608		1,328
Change in Plan Assets [Roll Forward]
Balance at beginning of period		1,301		1,173
Actual return on plan assets		(7)		173
Employer contributions		54		38
Participant contributions		0		0
Gross benefits paid		(59)		(83)	[6]
Balance at end of period		1,289		1,301		$ 1,173
Funded Status, end of period		(299)		(307)
Lump sum cash payouts made to terminated vested employees				33
Increase during the period resulting from a plan amendment		19		23
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset		0		0
Current liability		(3)		(3)
Noncurrent liability		(296)		(304)
Net amount recognized, end of period		(299)		(307)
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)		54		43
Net actuarial (gain) loss		338		354
Total		392		397
Total accumulated benefit obligation for defined benefit pension plans		1,452		1,461
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI		70		65
Regulatory assets/liabilities		322		332
Total		392		397
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Value of Plan Assets (Details) [Abstract]
Projected benefit obligations		1,588		1,608
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets		1,289		1,301
Accumulated benefit obligation		1,452		1,461
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets		$ 1,289		$ 1,301
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate		4.49%		4.06%
Benefit obligations valuation rate of compensation increase		3.50%		3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		4.06%		4.91%		3.99%
Net periodic benefit costs rate of compensation increase		3.50%		4.00%		4.00%
Net periodic benefit costs expected return on plan assets	[1]	6.82%		6.75%		6.76%
Effect of One Percentage Point Change in Assumed Health Care Costs Trend Rate (Details) [Abstract]
Effect on accumulated postretirement benefit obligation of a one percentage point increase		$ 5
Effect on accumulated postretirement benefit obligation of a one percentage point decrease		(4)
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		234		$ 193
Service cost		5		4		$ 5
Interest cost		9		9		8
Participant contributions		7		7
Plan amendments		0		6
Actuarial (gain) loss		(22)		32
Gross benefits paid		(18)		(17)
Benefit Obligation, end of period		216		234		193
Change in Plan Assets [Roll Forward]
Balance at beginning of period		82		74
Actual return on plan assets		0		10
Employer contributions		17		8
Participant contributions		7		7
Gross benefits paid		(18)		(17)
Balance at end of period		88		82		$ 74
Funded Status, end of period		(128)		(152)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset		2		2
Current liability		(3)		(3)
Noncurrent liability		(127)		(151)
Net amount recognized, end of period		(128)		(152)
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)		9		12
Net actuarial (gain) loss		(19)		(4)
Total		(10)		8
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI		7		8
Regulatory assets/liabilities		(17)		0
Total		$ (10)		$ 8
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate		4.49%		4.20%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		4.20%		5.13%		4.20%
Net periodic benefit costs expected return on plan assets	[1]	7.00%		7.00%		7.10%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 331		$ 291
Service cost		1		1		$ 2
Interest cost		14		15		14
Plan amendments		10	[7]	9
Actuarial (gain) loss		(15)		36
Gross benefits paid		(15)	[8]	(21)
Benefit Obligation, end of period		326		331		291
Change in Plan Assets [Roll Forward]
Balance at beginning of period		301		281
Actual return on plan assets		(2)		41
Employer contributions		13		0
Gross benefits paid		(15)		(21)	[8]
Balance at end of period		297		301		$ 281
Funded Status, end of period		(29)		(30)
Lump sum cash payouts made to terminated vested employees				8
Increase during the period resulting from a plan amendment		10		9
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent liability		(29)		(30)
Net amount recognized, end of period		(29)		(30)
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)		29		22
Net actuarial (gain) loss		95		98
Total		124		120
Total accumulated benefit obligation for defined benefit pension plans		326		330
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total		124		120
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period		26		27
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits United States [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period		77		85
Kentucky Utilities Co [Member] | Pension Benefits United States [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period		46		59
Kentucky Utilities Co [Member] | Other Postretirement Benefits United States [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period		$ 42		$ 52
[1]	The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
[2]	As a result of the spinoff of PPL Energy Supply, obligations and assets attributable to certain former active and inactive employees of PPL Energy Supply were transferred to Talen Energy plans.
[3]	Certain U.S. pension plans offered a limited-time program in 2014 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump sum payment. G ross benefits paid i ncludes $33 million of lump-sum cash pa yments made to terminated vested participants in 2014 in connection with these offerings.
[4]	WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and a s a result, does not record regulatory assets/lia bilities .
[5]	The pension plans were amended in December 2015 allowing terminated vested participants to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. The projected benefit obligation increased by $ 19 million as a result of the amendment. The plans were amended in December 2014 to enhance the early retirement factors for all plan participants retiring on or after January 1, 2015. These modifications resulted in an increase o f $ 23 million in the plans’ projected benefit obligations as of December 31, 2014.
[6]	Certain LKE pension plans offered a limited-time program in 2014 during which terminated vested participants could elect to receive thei r accrued pension benefit as a one-time lump-sum payment. The gross benefits paid includes $ 33 million of lump-sum cash payments made to terminated vested participants during 2014 in connection with these offerings.
[7]	The plan was amended in December 2015 allowing terminated vested participants to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. The projected benefit obligation increased by $ 10 million as a result of the amendment. The plan was amended in December 2014 to enhance the early retirement factors for all plan participants retirin g on or after January 1, 2015. Th e projected benefit obligation increased by $ 9 million as a result of the amendment.
[8]	LG&E's pension plan offered a limited-time program in 2014 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The gross benefits paid includes $ 8 million of lump-sum cash payments made to terminated vested participants in 2014 in connection with this offering.

Retirement and Postemployment78

Retirement and Postemployment Benefits (Plan Assets and Expected Cash Flows) (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)Integer	Dec. 31, 2014USD ($)	Dec. 31, 2015USD ($)		Dec. 31, 2014USD ($)
Pension Benefits United States [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 4,462	$ 4,462	$ 3,227		$ 4,462
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		4,462	4,009
Balance at end of period		3,227	4,462
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Amount to be contributed to plan in the next fiscal year		$ 30
Expected amount of benefit payments in the next period for non-qualified plans				10
Estimated Future Benefit Payments (Details) [Abstract]
2,016				234
2,017				245
2,018				250
2,019				259
2,020				261
2021-2025				1,333
Pension Benefits United States [Member] | Master Trust [Member]
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)		10
The limited lives of fifth partnership of private equity investments (in years)		15
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership				$ 27
Minimum number of days notice required to redeem shares for investments in hedge funds | Integer		60
Maximum number of days notice required to redeem shares for investments in hedge funds | Integer		95
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				100.00%	[1]	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 3,387	4,809	$ 3,387		$ 4,809
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		4,809
Balance at end of period		3,387	4,809
Expected Federal Subsidy (Details) [Abstract]
Assets transferred to Talen Energy as a result of the spinoff				1,159
Assets transferred to Talen Energy for PPL Montana				170
Pension Benefits United States [Member] | Master Trust [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		1,211	1,211	889		1,211
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,211
Balance at end of period		889	1,211
Pension Benefits United States [Member] | Master Trust [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		1,228	1,228	851		1,228
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,228
Balance at end of period		851	1,228
Pension Benefits United States [Member] | Master Trust [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		54	54	42		54
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		54	60
Actual return on plan assets relating to assets still held at the reporting date		2	0
Actual return on plan assets relating to assets sold during the period		(1)	(1)
Purchases, sales and settlements		(13)	(5)
Balance at end of period		42	54
Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				225		246
Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				225		246
Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			197		318
Measured at fair value not using net asset value per share				87		114
Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				87		114
Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				85		145
Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				85		145
Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | International Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			454		615
Pension Benefits United States [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			514		818
Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				501		723
Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				492		706
Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				9		17
Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				3		2
Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				3		2
Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				747		1,109
Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				737		1,088
Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				10		21
Fair value at end of period			23
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			23
Actual return on plan assets relating to assets still held at the reporting date		0	(1)
Actual return on plan assets relating to assets sold during the period		(1)	(1)
Purchases, sales and settlements		(10)	0
Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				4		8
Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				4		8
Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				7		9
Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				7		9
Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Commodities Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			70		90
Pension Benefits United States [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			118		148
Pension Benefits United States [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			81		104
Pension Benefits United States [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			171		223
Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				80		92
Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				80		92
Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				11		12
Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				11		12
Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				32		33
Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				32		33
Fair value at end of period			37
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			37
Actual return on plan assets relating to assets still held at the reporting date		2	1
Actual return on plan assets relating to assets sold during the period		0	0
Purchases, sales and settlements		(3)	(5)
Pension Benefits United States [Member] | Master Trust [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	[3]	(41)	(41)	(49)		(41)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	[3]	(41)
Balance at end of period	[3]	(49)	(41)
Pension Benefits United States [Member] | Master Trust [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		(136)	(136)	(111)		(136)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		(136)
Balance at end of period		(111)	(136)
Pension Benefits United States [Member] | Master Trust [Member] | Total Trust Assets Not Including 401 H Assets [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	[4]	4,632	4,632	$ 3,227		$ 4,632
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	[4]	4,632
Balance at end of period	[4]	$ 3,227	4,632
Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				51.00%	[1]	51.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	50.00%
Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				25.00%	[1]	26.00%
Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[5]			13.00%	[1]	13.00%
Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				13.00%	[1]	12.00%
Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				47.00%	[1]	47.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	48.00%
Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[5]			42.00%	[1]	44.00%
Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				5.00%	[1]	3.00%
Pension Benefits United States [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				2.00%	[1]	2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	2.00%
Pension Benefits United Kingdom [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				100.00%		100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 7,734	7,284	$ 7,625		$ 7,734
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		7,734	7,284
Balance at end of period		7,625	7,734
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Amount to be contributed to plan in the next fiscal year		$ 364
Recurrence of formal actuarial valuations (in years) | Integer		3
Percentage of deficit funding requirements permitted to recover in rates		78.00%
Estimated Future Benefit Payments (Details) [Abstract]
2,016				379
2,017				384
2,018				391
2,019				397
2,020				402
2021-2025				2,074
Pension Benefits United Kingdom [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 55	57	55		57
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		57
Balance at end of period		55	57
Pension Benefits United Kingdom [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		2,271	2,271	3,009		2,271
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		2,271
Balance at end of period		3,009	2,271
Pension Benefits United Kingdom [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		0	0	$ 0		$ 0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		0
Balance at end of period		$ 0	0
Pension Benefits United Kingdom [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				1.00%		1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		0.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				$ 55		$ 57
Pension Benefits United Kingdom [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				55		57
Pension Benefits United Kingdom [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United Kingdom [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				$ 0		$ 0
Pension Benefits United Kingdom [Member] | UK Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				3.00%		3.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		4.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 274		$ 239
Pension Benefits United Kingdom [Member] | European Companies Excluding UK Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				2.00%		3.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		3.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 190		$ 198
Pension Benefits United Kingdom [Member] | Asian Pacific Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				2.00%		2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		2.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 132		$ 142
Pension Benefits United Kingdom [Member] | North American Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				3.00%		3.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		3.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 220		$ 227
Pension Benefits United Kingdom [Member] | Emerging Markets Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				10.00%		9.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		10.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 284		$ 309
Pension Benefits United Kingdom [Member] | Global Equities Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 500		$ 397
Pension Benefits United Kingdom [Member] | Currency Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				1.00%		2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		1.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 39		$ 190
Pension Benefits United Kingdom [Member] | Global Tactical Asset Allocation Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				31.00%		29.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		31.00%
Pension Benefits United Kingdom [Member] | Other Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share				$ 2,384		$ 2,263
Pension Benefits United Kingdom [Member] | UK Corporate Bonds Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share				92		2
Pension Benefits United Kingdom [Member] | UK Gilts Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share				$ 3		$ 913
Pension Benefits United Kingdom [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[7]			40.00%		42.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[7]	39.00%
Pension Benefits United Kingdom [Member] | United Kingdom Corporate Bonds Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				$ 364		$ 344
Pension Benefits United Kingdom [Member] | United Kingdom Corporate Bonds Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United Kingdom [Member] | United Kingdom Corporate Bonds Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				364		344
Pension Benefits United Kingdom [Member] | United Kingdom Corporate Bonds Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United Kingdom [Member] | United Kingdom Gilts Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				2,645		1,927
Pension Benefits United Kingdom [Member] | United Kingdom Gilts Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Pension Benefits United Kingdom [Member] | United Kingdom Gilts Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				2,645		1,927
Pension Benefits United Kingdom [Member] | United Kingdom Gilts Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				$ 0		$ 0
Pension Benefits United Kingdom [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				7.00%		6.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		7.00%
Pension Benefits United Kingdom [Member] | Real Estate Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[6]			$ 533		$ 436
Other Postretirement Benefits United States [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				100.00%		100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 379	446	$ 379		$ 484
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		484	446
Balance at end of period		379	484
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Amount to be contributed to plan in the next fiscal year		$ 13
Estimated Future Benefit Payments (Details) [Abstract]
2,016				54
2,017				53
2,018				53
2,019				53
2,020				52
2021-2025				244
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2016				1
Federal subsidy 2017				1
Federal subsidy 2018				1
Federal subsidy 2019				1
Federal subsidy 2020				1
Federal subsidy 2021-2025				2
Assets transferred to Talen Energy as a result of the spinoff				$ 80
Other Postretirement Benefits United States [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[8]			2.00%		2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[8]	5.00%
Other Postretirement Benefits United States [Member] | Money Market Funds [Member]
Assumptions Used in Calculations (Numeric) [Abstract]
Number of months from date of purchase that investment must mature | Integer		13
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 9	9	$ 6		$ 9
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		9
Balance at end of period		$ 6	9
Other Postretirement Benefits United States [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				48.00%		49.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average		45.00%
Other Postretirement Benefits United States [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[9]			50.00%		49.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[9]	50.00%
Other Postretirement Benefits United States [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 1	1	$ 1		$ 1
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1
Balance at end of period		1	1
Other Postretirement Benefits United States [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		136	136	111		136
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		136
Balance at end of period		111	136
Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		267	347	267		347
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		347
Balance at end of period		267	347
Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		9	9	6		9
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		9
Balance at end of period		6	9
Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		23	33	23		33
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		33
Balance at end of period		23	33
Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		0	0	0		0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		0
Balance at end of period		0	0
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Money Market Funds [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				6		9
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Money Market Funds [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Money Market Funds [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Other Postretirement Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[10]			129		169
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share				109		136
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Municipalities Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				23		33
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Municipalities Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Municipalities Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				23		33
Other Postretirement Benefits United States [Member] | Master Trust [Member] | Municipalities Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		1,289	1,173	1,289		1,301
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,301	1,173
Balance at end of period		1,289	$ 1,301
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Amount to be contributed to plan in the next fiscal year		$ 30
Expected amount of benefit payments in the next period for non-qualified plans				3
Estimated Future Benefit Payments (Details) [Abstract]
2,016				95
2,017				100
2,018				102
2,019				105
2,020				107
2021-2025				550
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member]
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary				1,300		$ 1,300
Undivided interest percentage in each asset category that PPL subsidiary holds		40.00%	28.00%
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)		10
The limited lives of fifth partnership of private equity investments (in years)		15
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership				$ 27
Minimum number of days notice required to redeem shares for investments in hedge funds | Integer		60
Maximum number of days notice required to redeem shares for investments in hedge funds | Integer		95
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				100.00%	[1]	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 3,387	$ 4,809	$ 3,387		$ 4,809
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		4,809
Balance at end of period		3,387	4,809
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		889	1,211	889		1,211
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,211
Balance at end of period		889	1,211
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		1,228	1,228	851		1,228
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,228
Balance at end of period		851	1,228
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		42	54	42		54
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		54	60
Actual return on plan assets relating to assets still held at the reporting date		2	0
Actual return on plan assets relating to assets sold during the period		(1)	(1)
Purchases, sales and settlements		(13)	(5)
Balance at end of period		42	54
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				225		246
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				225		246
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			197		318
Measured at fair value not using net asset value per share				87		114
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				87		114
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				85		145
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				85		145
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			454		615
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			514		818
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				501		723
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				492		706
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				9		17
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				3		2
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				3		2
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				747		1,109
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				737		1,088
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				10		21
Fair value at end of period			23
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			23
Actual return on plan assets relating to assets still held at the reporting date		0	(1)
Actual return on plan assets relating to assets sold during the period		(1)	(1)
Purchases, sales and settlements		(10)	0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				4		8
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				4		8
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				7		9
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				7		9
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Commodities Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			70		90
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			118		148
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			81		104
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			171		223
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				80		92
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				80		92
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				11		12
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				11		12
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				32		33
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				32		33
Fair value at end of period			37
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			37
Actual return on plan assets relating to assets still held at the reporting date		2	1
Actual return on plan assets relating to assets sold during the period		0	0
Purchases, sales and settlements		(3)	(5)
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	[3]	(41)	(41)	(49)		(41)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	[3]	(41)
Balance at end of period	[3]	(49)	(41)
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		(136)	(136)	(111)		(136)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		(136)
Balance at end of period		(111)	(136)
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Total Trust Assets Not Including 401 H Assets [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	[4]	4,632	4,632	$ 3,227		$ 4,632
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	[4]	4,632
Balance at end of period	[4]	$ 3,227	4,632
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				51.00%	[1]	51.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	50.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				25.00%	[1]	26.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[5]			13.00%	[1]	13.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				13.00%	[1]	12.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				47.00%	[1]	47.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	48.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[5]			42.00%	[1]	44.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				5.00%	[1]	3.00%
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				2.00%	[1]	2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	2.00%
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 88	74	$ 88		$ 82
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		82	74
Balance at end of period		88	82
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Amount to be contributed to plan in the next fiscal year		$ 13
Estimated Future Benefit Payments (Details) [Abstract]
2,016				13
2,017				14
2,018				15
2,019				16
2,020				16
2021-2025				85
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2016				0
Federal subsidy 2017				0
Federal subsidy 2018				1
Federal subsidy 2019				0
Federal subsidy 2020				0
Federal subsidy 2021-2025				2
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member] | Money Market Funds [Member]
Assumptions Used in Calculations (Numeric) [Abstract]
Number of months from date of purchase that investment must mature | Integer		13
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 6	9	6		9
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		9
Balance at end of period		6	9
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		347	347	267		347
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		347
Balance at end of period		267	347
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		6	9	6		9
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		9
Balance at end of period		6	9
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		23	33	23		33
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		33
Balance at end of period		23	33
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member] | Total Trust Assets Not Including 401 H Assets [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		0	0	0		0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		0
Balance at end of period		0	0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		297	281	297		301
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		301	281
Balance at end of period		297	$ 301
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Amount to be contributed to plan in the next fiscal year		$ 7
Estimated Future Benefit Payments (Details) [Abstract]
2,016				23
2,017				25
2,018				24
2,019				25
2,020				25
2021-2025				111
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member]
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary				297		$ 301
Undivided interest percentage in each asset category that PPL subsidiary holds		9.00%	6.00%
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)		10
The limited lives of fifth partnership of private equity investments (in years)		15
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership				$ 27
Minimum number of days notice required to redeem shares for investments in hedge funds | Integer		60
Maximum number of days notice required to redeem shares for investments in hedge funds | Integer		95
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				100.00%	[1]	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		$ 3,387	$ 4,809	$ 3,387		$ 4,809
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		4,809
Balance at end of period		3,387	4,809
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		889	1,211	889		1,211
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,211
Balance at end of period		889	1,211
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		1,228	1,228	851		1,228
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		1,228
Balance at end of period		851	1,228
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		54	54	42		54
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		54	60
Actual return on plan assets relating to assets still held at the reporting date		2	0
Actual return on plan assets relating to assets sold during the period		(1)	(1)
Purchases, sales and settlements		(13)	(5)
Balance at end of period		42	54
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				225		246
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				225		246
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			197		318
Measured at fair value not using net asset value per share				87		114
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				87		114
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Large Cap Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				85		145
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				85		145
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | United States Small Cap Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			454		615
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			514		818
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				501		723
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				492		706
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				9		17
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				3		2
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				3		2
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Residential - Commercial Backed Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				747		1,109
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				737		1,088
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				10		21
Fair value at end of period			23
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			23
Actual return on plan assets relating to assets still held at the reporting date		0	(1)
Actual return on plan assets relating to assets sold during the period		(1)	(1)
Purchases, sales and settlements		(10)	0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				4		8
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				4		8
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | International Government Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				7		9
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				7		9
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Commodities Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			70		90
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			118		148
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			81		104
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	[2]			171		223
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				80		92
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				80		92
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Interest Rate Swaps And Swaptions Derivatives [ Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				11		12
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				11		12
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Other Derivatives [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				32		33
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				0		0
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share				32		33
Fair value at end of period			37
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			37
Actual return on plan assets relating to assets still held at the reporting date		2	1
Actual return on plan assets relating to assets sold during the period		0	0
Purchases, sales and settlements		(3)	(5)
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	[3]	(41)	(41)	(49)		(41)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	[3]	(41)
Balance at end of period	[3]	(49)	(41)
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		(136)	(136)	(111)		(136)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period		(136)
Balance at end of period		(111)	(136)
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Total Trust Assets Not Including 401 H Assets [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	[4]	4,632	4,632	$ 3,227		$ 4,632
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	[4]	4,632
Balance at end of period	[4]	$ 3,227	$ 4,632
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				51.00%	[1]	51.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	50.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				25.00%	[1]	26.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[5]			13.00%	[1]	13.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				13.00%	[1]	12.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				47.00%	[1]	47.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	48.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	[5]			42.00%	[1]	44.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				5.00%	[1]	3.00%
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets				2.00%	[1]	2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation, weighted average	[1]	2.00%
[1]	Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan.
[2]	In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.
[3]	Receivables and payables represent amounts for investments sold/purchased but not yet settled alon g with interest and dividends earned but not yet received.
[4]	As a result of the spinoff of PPL Energy Supply, $1,159 million of assets were transferred to Talen Energy in 2015, attributable to former active and inactive employees of PPL Energy Supply that had participated in PPL’s pension plan. An additional $170 million of assets of the PPL Montana pension plan transferred to Talen Energy, as that entire plan was assumed by Talen Energy.
[5]	Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes .
[6]	In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.
[7]	Includes commingled debt funds.
[8]	Includes money market fund s .
[9]	Includes commingled debt funds and debt securities.
[10]	In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.

Retirement and Postemployment79

Retirement and Postemployment Benefits (Savings Plans and Employee Stock Ownership Plan) (Details) - Deferred Savings Plans 401K [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 34	$ 33	$ 29
PPL Electric Utilities Corp [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	6	6	6
LG And E And KU Energy LLC [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	16	15	13
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	5	5	7
Kentucky Utilities Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 4	$ 4	$ 6

Jointly Owned Facilities (Detai

Jointly Owned Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 399	$ 309
Accumulated depreciation	44	51
Construction work in progress	$ 6	$ 59
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,013	$ 1,002
Accumulated depreciation	141	122
Construction work in progress	$ 27	$ 32
LG And E And KU Energy LLC [Member] | Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 399	$ 309
Accumulated depreciation	44	51
Construction work in progress	$ 6	$ 59
LG And E And KU Energy LLC [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,013	$ 1,002
Accumulated depreciation	141	122
Construction work in progress	$ 27	$ 32
Louisville Gas And Electric Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	38.00%	38.00%
Electric plant	$ 40	$ 40
Accumulated depreciation	12	10
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	53.00%	53.00%
Electric plant	$ 47	$ 47
Accumulated depreciation	10	7
Construction work in progress	$ 1	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 399	$ 309
Accumulated depreciation	44	51
Construction work in progress	$ 6	$ 59
Louisville Gas And Electric Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	14.25%	14.25%
Electric plant	$ 210	$ 205
Accumulated depreciation	28	23
Construction work in progress	$ 12	$ 15
Louisville Gas And Electric Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	29.00%	29.00%
Electric plant	$ 29	$ 29
Accumulated depreciation	6	5
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	37.00%	37.00%
Electric plant	$ 71	$ 70
Accumulated depreciation	14	11
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	22.00%	22.00%
Electric plant	$ 115	$ 0
Accumulated depreciation	1	0
Construction work in progress	$ 1	$ 113
Louisville Gas And Electric Co [Member] | E W Brown Solar Unit [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	39.00%
Electric plant	$ 0
Accumulated depreciation	0
Construction work in progress	$ 4
Kentucky Utilities Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	62.00%	62.00%
Electric plant	$ 65	$ 65
Accumulated depreciation	19	15
Construction work in progress	$ 0	$ 1
Kentucky Utilities Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	47.00%	47.00%
Electric plant	$ 43	$ 42
Accumulated depreciation	9	6
Construction work in progress	$ 1	$ 0
Kentucky Utilities Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	60.75%	60.75%
Electric plant	$ 803	$ 797
Accumulated depreciation	113	98
Construction work in progress	$ 15	$ 17
Kentucky Utilities Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	71.00%	71.00%
Electric plant	$ 70	$ 70
Accumulated depreciation	15	11
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	63.00%	63.00%
Electric plant	$ 121	$ 120
Accumulated depreciation	23	18
Construction work in progress	$ 0	$ 1
Kentucky Utilities Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	78.00%	78.00%
Electric plant	$ 411	$ 0
Accumulated depreciation	6	0
Construction work in progress	$ 5	$ 403
Kentucky Utilities Co [Member] | E W Brown Solar Unit [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	61.00%
Electric plant	$ 0
Accumulated depreciation	0
Construction work in progress	$ 6

Commitments and Contingencies81

Commitments and Contingencies (Energy Purchases, Energy Sales, Other Commitments and Legal Matters) (Details) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Mar. 31, 2015Integer	Jun. 30, 2015Integer	Dec. 31, 2015USD ($)Integermi	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | Integer			6
Number of miles within plant that would include a class of residents | mi			4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | Integer			1
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]
Maximum per day penalties for reliability violations			$ 1
Power Purchase [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2,016			26
2,017			27
2,018			27
2,019			28
2,020			29
Thereafter			628
Total future obligation			765
Purchases			$ 22	$ 25	$ 26
Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,022
Coal Transporation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
Natural Gas Storage [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026
LGE [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Generating units retired at the Cane Run plant | Integer	1	2
PPL Electric Utilities Corp [Member]
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]
Maximum per day penalties for reliability violations			$ 1
LG And E And KU Energy LLC [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | Integer			6
Number of miles within plant that would include a class of residents | mi			4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | Integer			1
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]
Maximum per day penalties for reliability violations			$ 1
LG And E And KU Energy LLC [Member] | Power Purchase [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2,016			26
2,017			27
2,018			27
2,019			28
2,020			29
Thereafter			628
Total future obligation			765
Purchases			$ 22	25	26
LG And E And KU Energy LLC [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,022
LG And E And KU Energy LLC [Member] | Coal Transporation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
LG And E And KU Energy LLC [Member] | Natural Gas Storage [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
LG And E And KU Energy LLC [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026
LG And E And KU Energy LLC [Member] | LGE [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Generating units retired at the Cane Run plant | Integer	1	2
Louisville Gas And Electric Co [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | Integer			6
Number of miles within plant that would include a class of residents | mi			4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | Integer			1
Generating units retired at the Cane Run plant | Integer	1	2
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]
Maximum per day penalties for reliability violations			$ 1
Louisville Gas And Electric Co [Member] | Power Purchase [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2,016			18
2,017			19
2,018			19
2,019			19
2,020			20
Thereafter			435
Total future obligation			530
Purchases			$ 15	17	18
Louisville Gas And Electric Co [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,022
Louisville Gas And Electric Co [Member] | Coal Transporation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
Louisville Gas And Electric Co [Member] | Natural Gas Storage [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
Louisville Gas And Electric Co [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026
Kentucky Utilities Co [Member]
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]
Maximum per day penalties for reliability violations			$ 1
Kentucky Utilities Co [Member] | Power Purchase [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2,016			8
2,017			8
2,018			8
2,019			9
2,020			9
Thereafter			193
Total future obligation			235
Purchases			$ 7	$ 8	$ 8
Kentucky Utilities Co [Member] | Coal [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,022
Kentucky Utilities Co [Member] | Coal Transporation And Fleeting Services [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
Kentucky Utilities Co [Member] | Natural Gas Storage [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,024
Kentucky Utilities Co [Member] | Natural Gas Transportation [Member]
Energy Purchase Commitments (Numeric) [Abstract]
Maximum maturity date			2,026

Commitments and Contingencies82

Commitments and Contingencies (Environmental Matter and Other) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Environmental site accrual	$ 10
Potential costs for remediation and other liabilities	30
LGE [Member] | Mercury And Air Toxics [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	5
LGE [Member] | LGE And KU Sites [Member] | Coal Combustion Residuals [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	311
KU [Member] | Mercury And Air Toxics [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	17
KU [Member] | LGE And KU Sites [Member] | Coal Combustion Residuals [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	661
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Environmental site accrual	10
Potential costs for remediation and other liabilities	30
LG And E And KU Energy LLC [Member] | LGE [Member] | Mercury And Air Toxics [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	5
LG And E And KU Energy LLC [Member] | LGE [Member] | LGE And KU Sites [Member] | Coal Combustion Residuals [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	311
LG And E And KU Energy LLC [Member] | KU [Member] | Mercury And Air Toxics [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	17
LG And E And KU Energy LLC [Member] | KU [Member] | LGE And KU Sites [Member] | Coal Combustion Residuals [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	661
Louisville Gas And Electric Co [Member] | Mercury And Air Toxics [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	5
Louisville Gas And Electric Co [Member] | LGE And KU Sites [Member] | Coal Combustion Residuals [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	311
Kentucky Utilities Co [Member] | Mercury And Air Toxics [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	17
Kentucky Utilities Co [Member] | LGE And KU Sites [Member] | Coal Combustion Residuals [Member]
Environmental Matters - Domestic (Numeric) [Abstract]
Potential costs for compliance	$ 661

Commitments and Contingencies83

Commitments and Contingencies (Guarantees and Other Assurances) (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)Integer	Dec. 31, 2014USD ($)
Guarantor Obligations [Line Items]
Recorded liability for all guarantees		$ 25	$ 26
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage		$ 225
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications Related To WPD Midlands Acquisition [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable		The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications For Entities In Liquidation Sales Of Assets [Member]
Guarantor Obligations [Line Items]
Maximum exposure	[1]	$ 11
Expiration date		2,019
Minimum period that indemnifications generally expire (in years) | Integer		2
Maximum period that indemnifications generally expire (in years) | Integer		7
PPL Guarantee [Member] | Financial Guarantee [Member] | WPD Guarantee Of Pension And Other Obligations Of Unconsolidated Entities [Member]
Guarantor Obligations [Line Items]
Maximum exposure	[2]	$ 114
PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	[3]	$ 29
Expiration date		2,018
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure	[4]	$ 301
Expiration date minimum		2,021
Expiration date maximum		2,023
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 guarantees expiring related to a terminated lease		$ 100
LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable		The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent potential proportionate share of OVEC's outstanding debt		$ 124
PPL Electric Utilities Corp [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	[3]	$ 29
Expiration date		2,018
LG And E And KU Energy LLC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees		$ 18	$ 19
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	[4]	$ 301
Expiration date minimum		2,021
Expiration date maximum		2,023
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 guarantees expiring related to a terminated lease		$ 100
LG And E And KU Energy LLC [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable		The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent potential proportionate share of OVEC's outstanding debt		$ 124
Louisville Gas And Electric Co [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable		The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent potential proportionate share of OVEC's outstanding debt		$ 86
Kentucky Utilities Co [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable		The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent potential proportionate share of OVEC's outstanding debt		$ 38
[1]	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 ei ther prior o r 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. Finally, WPD and its affiliates remain secondarily responsible for lease payments under certain leases that they have assigned to third parties.
[2]	Relates to certain obligations of discontinued or modified ele ctric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent . At December 31, 2015 , WPD has recorded an estimated discou nted 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 .
[3]	A third party logistics firm provides inventory procurement and fulfillment services. T he logistics firm has title to the inventory , however, u pon termination of the contract s , PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold .
[4]	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 fall outside the cap. Another WKE-related LKE guarantee covers other indemnifications related to the p urchase 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 Oct ober 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. LKE does not believe appropriate contractual, legal or commercial grounds exist for the claim s made and has disputed the demand s . LKE believes its indemnification obligations in the WKE matter remain subject to various uncertain ties, including additional legal and contractual developments, as well as future prices, availability and demand for the subject excess power. The parties are conducting preliminary settlement discussions, however, the ultimate outcomes of the WKE termina tion-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 ou tcomes of the indemnification circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded.

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	$ 125	$ 151	$ 146
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	60	0	0
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	54	41
Long-term debt to affiliate	400	0
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	$ 16	$ 15	15
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing	1.74%	1.65%
Notes payable to affiliates	$ 54	$ 41
Intercompany note with affiliate maximum borrowing capacity	225
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	$ 300
LG And E And KU Energy LLC [Member] | PPL Capital Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing	3.50%
Long-term debt to affiliate	$ 400
Louisville Gas And Electric Co [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates	155	140	136
Kentucky Utilities Co [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates	$ 185	$ 165	$ 160

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Other Income [Line Items]
Interest income	$ 4	$ 1	$ 0
Allowance for funds used during construction - equity component	14	11	10
Miscellaneous	6	7	4
Other income	24	19	14
Other Expense [Line Items]
Economic foreign currency exchange contracts	(122)	(121)	38
Charitable contributions	21	27	21
Miscellaneous	17	8	10
Other expense	(84)	(86)	69
Other Income (Expense) - net	108	105	(55)
PPL Electric Utilities Corp [Member]
Other Expense [Line Items]
Other Income (Expense) - net	8	7	6
LG And E And KU Energy LLC [Member]
Other Expense [Line Items]
Other Income (Expense) - net	(8)	(9)	(7)
Louisville Gas And Electric Co [Member]
Other Expense [Line Items]
Other Income (Expense) - net	(6)	(3)	(2)
Kentucky Utilities Co [Member]
Other Expense [Line Items]
Other Income (Expense) - net	$ 1	$ (1)	$ (3)

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - Recurring [Member] - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Assets
Cash and cash equivalents		$ 836	$ 1,399
Short-term investments		0	120
Restricted cash and cash equivalents	[1]	33	31
Price risk management assets:
Foreign currency contracts assets	[2]	209	130
Cross-currency swaps assets	[2]	86	29
Total price risk management assets	[2]	295	159
Auction rate securities	[3]	2	2
Total assets		1,166	1,711
Price risk management liabilities:
Interest rate swaps liabilities	[2]	71	156
Foreign currency contracts liabilities	[2]	1	2
Cross-currency swaps liabilities	[2]	0	3
Total price risk management liabilities	[2]	72	161
Level 1 [Member]
Assets
Cash and cash equivalents		836	1,399
Short-term investments		0	120
Restricted cash and cash equivalents	[1]	33	31
Price risk management assets:
Foreign currency contracts assets		0	0
Cross-currency swaps assets		0	0
Total price risk management assets		0	0
Auction rate securities		0	0
Total assets		869	1,550
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Foreign currency contracts liabilities		0	0
Cross-currency swaps liabilities		0	0
Total price risk management liabilities		0	0
Level 2 [Member]
Assets
Cash and cash equivalents		0	0
Short-term investments		0	0
Restricted cash and cash equivalents		0	0
Price risk management assets:
Foreign currency contracts assets	[2]	209	130
Cross-currency swaps assets	[2]	86	28
Total price risk management assets	[2]	295	158
Auction rate securities		0	0
Total assets		295	158
Price risk management liabilities:
Interest rate swaps liabilities	[2]	71	156
Foreign currency contracts liabilities	[2]	1	2
Cross-currency swaps liabilities		0	3	[2]
Total price risk management liabilities	[2]	72	161
Level 3 [Member]
Assets
Cash and cash equivalents		0	0
Short-term investments		0	0
Restricted cash and cash equivalents		0	0
Price risk management assets:
Foreign currency contracts assets		0	0
Cross-currency swaps assets		0	1	[2]
Total price risk management assets		0	1	[2]
Auction rate securities	[3]	2	2
Total assets		2	3
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Foreign currency contracts liabilities		0	0
Cross-currency swaps liabilities		0	0
Total price risk management liabilities		0	0
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents		47	214
Restricted cash and cash equivalents	[1]	2	3
Price risk management assets:
Total assets		49	217
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents		47	214
Restricted cash and cash equivalents	[1]	2	3
Price risk management assets:
Total assets		49	217
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		30	21
Price risk management assets:
Cash collateral posted to counterparties	[4]	9	21
Total assets		39	42
Price risk management liabilities:
Interest rate swaps liabilities		47	114
Total price risk management liabilities		47	114
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents		30	21
Price risk management assets:
Cash collateral posted to counterparties	[4]	9	21
Total assets		39	42
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Total price risk management liabilities		0	0
LG And E And KU Energy LLC [Member] | Level 2 [Member]
Assets
Cash and cash equivalents		0	0
Price risk management assets:
Cash collateral posted to counterparties		0	0
Total assets		0	0
Price risk management liabilities:
Interest rate swaps liabilities		47	114
Total price risk management liabilities		47	114
LG And E And KU Energy LLC [Member] | Level 3 [Member]
Assets
Cash and cash equivalents		0	0
Price risk management assets:
Cash collateral posted to counterparties		0	0
Total assets		0	0
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Total price risk management liabilities		0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents		19	10
Price risk management assets:
Cash collateral posted to counterparties	[4]	9	21
Total assets		28	31
Price risk management liabilities:
Interest rate swaps liabilities		47	81
Total price risk management liabilities		47	81
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents		19	10
Price risk management assets:
Cash collateral posted to counterparties	[4]	9	21
Total assets		28	31
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Total price risk management liabilities		0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents		0	0
Price risk management assets:
Cash collateral posted to counterparties		0	0
Total assets		0	0
Price risk management liabilities:
Interest rate swaps liabilities		47	81
Total price risk management liabilities		47	81
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents		0	0
Price risk management assets:
Cash collateral posted to counterparties		0	0
Total assets		0	0
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Total price risk management liabilities		0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents		11	11
Price risk management assets:
Total assets		11	11
Price risk management liabilities:
Interest rate swaps liabilities		0	33
Total price risk management liabilities		0	33
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents		11	11
Price risk management assets:
Total assets		11	11
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Total price risk management liabilities		0	0
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents		0	0
Price risk management assets:
Total assets		0	0
Price risk management liabilities:
Interest rate swaps liabilities		0	33
Total price risk management liabilities		0	33
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents		0	0
Price risk management assets:
Total assets		0	0
Price risk management liabilities:
Interest rate swaps liabilities		0	0
Total price risk management liabilities		$ 0	$ 0
[1]	Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
[2]	Included in "Price risk management assets ", "Other current liabilities", "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
[3]	I ncluded in "Other current assets" on the Balance Sheets.
[4]	Included in "Other non current 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 Measurements (Financ

Fair Value Measurements (Financial Instruments Not Recorded at Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 19,048	$ 18,054
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	21,218	20,466
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,828	2,581
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	3,088	2,990
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,088	4,543
LG And E And KU Energy LLC [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,384	4,946
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	1,642	1,345
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	1,704	1,455
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,326	2,079
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 2,467	$ 2,313

Derivative Instruments and He88

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($)	Dec. 31, 2015	Dec. 31, 2014
Master Netting Arrangements (Numeric) [Line Items]
No or immaterial obligation to return cash collateral obligation under master netting arrangement	$ 0	$ 0
Cash collateral posted under master netting arrangements	9,000,000	21,000,000
LG And E And KU Energy LLC [Member]
Master Netting Arrangements (Numeric) [Line Items]
No or immaterial obligation to return cash collateral obligation under master netting arrangement	0	0
Cash collateral posted under master netting arrangements	9,000,000	21,000,000
Louisville Gas And Electric Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
No or immaterial obligation to return cash collateral obligation under master netting arrangement	0	0
Cash collateral posted under master netting arrangements	9,000,000	21,000,000
Kentucky Utilities Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
No or immaterial obligation to return cash collateral obligation under master netting arrangement	$ 0	$ 0

Derivative Instruments and He89

Derivative Instruments and Hedging Activities (Risk Disclosures) (Details) £ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2015GBP (£)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps	$ 101	$ 0	$ 0
Interest Rate Swap Contracts [Member] | First Mortgage Bonds [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Principal amount						$ 1,050
Cash Flow Hedges [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Insignificant or no hedge ineffectiveness associated with interest rate cash flow hedges	For 2015, 2014 and 2013, hedge ineffectiveness associated with interest rate derivatives was insignificant.
No or insignificant after-tax gains (losses) previously recorded in AOCI reclassified to earnings related to interest rate cash flow hedge contracts	For PPL's remaining cash flow hedges, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges in 2015 and 2013 and an insignificant amount reclassified into earnings associated with discontinued cash flow hedges in 2014.
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	At December 31, 2015, the accumulated net unrecognized after-tax gains (losses) on qualifying derivatives that are expected to be reclassified into earnings during the next 12 months were insignificant.
Cash Flow Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount					$ 300
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate cash flow hedge contracts	2,026
Cash Flow Hedges [Member] | Cross Currency Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount					1,300
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Earliest maturity date of cross-currency cash flow hedge contracts	2,016
Latest maturity date of cross-currency cash flow hedge contracts	2,028
Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount					179
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				£ 1,800	2,900
Earliest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity	January 2,016
Latest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity	December 2,017
Net Investment Hedges [Member] | Foreign Currency Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount				£ 50	84
Foreign Currency Risk - Net Investment Hedges (Numeric) [Abstract]
Earliest settlement date of net investment hedge contracts	May 2,016
Latest settlement date of net investment hedge contracts	June 2,016
Net after tax gains (losses) on net investment hedges recognized in the foreign currency translation adjustment component of AOCI	$ 19	14
LG And E And KU Energy LLC [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps	$ 88	0	0
LG And E And KU Energy LLC [Member] | Interest Rate Swap Contracts [Member] | First Mortgage Bonds [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Principal amount						1,050
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					179
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]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps	$ 44	0	0
Louisville Gas And Electric Co [Member] | Interest Rate Swap Contracts [Member] | First Mortgage Bonds [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Principal amount						550
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					$ 179
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate economic activity contracts	2,033
Kentucky Utilities Co [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Net cash settlements on terminated interest rate swaps	$ 44	$ 0	$ 0
Kentucky Utilities Co [Member] | Interest Rate Swap Contracts [Member] | First Mortgage Bonds [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Principal amount						$ 500

Derivative Instruments and He90

Derivative Instruments and Hedging Activities (Fair Values) (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014
Derivatives Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	$ 96		$ 46
Liability value	[1]	24		111
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	45		12
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		35	[1],[2]	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	10		12
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	51		34
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1],[2]	51		29
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		5	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[1]	24		97
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[1],[2]	24		94
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		3	[1],[2]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		14	[1]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		14	[1],[2]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		0
Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	199		113
Liability value	[1]	48		50
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	94		67
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	94		67
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	105		46
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	[1]	105		46
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[1]	6		5
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[1],[2]	5		5
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		0
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		1	[1]	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[1]	42		45
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[1],[2]	42		43
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		2	[1]
LG And E And KU Energy LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
LG And E And KU Energy LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		66	[3]
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Liability value	[3]	47		48
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0
Liability value	[3]	5		5
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[3]	5		5
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0
Liability value	[3]	42		43
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[3]	42		43
Louisville Gas And Electric Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Louisville Gas And Electric Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		0		33	[3]
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Liability value	[1]	47		48
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0
Liability value	[3]	5		5
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[3]	5		5
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0
Liability value	[3]	42		43
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	[3]	42		43
Kentucky Utilities Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value		0		0
Kentucky Utilities Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value		$ 0		$ 33	[3]
[1]	Included in "'Price r isk m anagement a ssets" of Current Assets, "Other current liabilities", "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheet s.
[2]	Excludes accrued interest, if applicable
[3]	Represents the location on the Balance Sheet.

Derivative Instruments and He91

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash Flow Hedges [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	$ 53	$ 85	$ 163
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(70)	2	1
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	26	(33)	86
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	(34)	(91)	127
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	(11)	(18)	(20)
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	2	0
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Discontinued Operations [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	0
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(77)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	60	58	(41)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	2	4	1
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	49	57	(28)
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Other Comprehensive Income [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in OCI on derivative (effective portion)	9	23	(14)
Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(22)	(66)	0
Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Regulatory Liabilities Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	0	0	72
Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [Member] | Commodity Contracts [Member] | Discontinued Operations [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	13	42	210
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	7	0	1
Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	114	113	(46)
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	1	(12)	22
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(8)	(8)	(8)
Derivatives Not Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	122	121	(38)
LG And E And KU Energy LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(22)	(66)	0
LG And E And KU Energy LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Regulatory Liabilities Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	0	0	72
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(12)	22
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(8)	(8)	(8)
Louisville Gas And Electric Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(11)	(33)	0
Louisville Gas And Electric Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Regulatory Liabilities Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	0	0	36
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(12)	22
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(8)	(8)	(8)
Kentucky Utilities Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [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	(11)	(33)	0
Kentucky Utilities Co [Member] | Derivatives Designated As Hedging Instruments [Member] | Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Regulatory Liabilities Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	$ 0	$ 0	$ 36

Derivative Instruments and He92

Derivative Instruments and Hedging Activities (Offseting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features		$ 28
Aggregate fair value of collateral posted on these derivative instruments		9
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	[1]	19
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets		295	$ 159
Derivative instruments eligible for offset - assets		25	65
Net assets		270	94
Gross liabilities		72	161
Derivative instruments eligible for offset - liabilities		25	65
Cash collateral pledged eligible for offset - liabilities		9	21
Net liabilities		38	75
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		28
Aggregate fair value of collateral posted on these derivative instruments		9
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	[1]	19
LG And E And KU Energy LLC [Member] | Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross liabilities		47	114
Cash collateral pledged eligible for offset - liabilities		9	20
Net liabilities		38	94
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		28
Aggregate fair value of collateral posted on these derivative instruments		9
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	[1]	19
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross liabilities		47	81
Cash collateral pledged eligible for offset - liabilities		9	20
Net liabilities		$ 38	61
Kentucky Utilities Co [Member] | Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross liabilities			33
Cash collateral pledged eligible for offset - liabilities			0
Net liabilities			$ 33
[1]	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Goodwill and Other Intangible93

Goodwill and Other Intangible Assets (Goodwill) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period		$ 3,667	$ 3,805	[1]
Effect of foreign currency exchange rates		(117)	(138)
Balance at end of period		3,550	3,667
Kentucky Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	[1]	662	662
Balance at end of period	[1]	662	662
United Kingdom Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	[1]	3,005	3,143
Effect of foreign currency exchange rates		(117)	(138)
Balance at end of period	[1]	2,888	3,005
LG And E And KU Energy LLC [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period		996
Balance at end of period		996	996
Louisville Gas And Electric Co [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period		389
Balance at end of period		389	389
Kentucky Utilities Co [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period		607
Balance at end of period		$ 607	$ 607
[1]	There were no accumulated impairment losses related to goodwill.

Goodwill and Other Intangible94

Goodwill and Other Intangible Assets (Other Intangibles) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subject to amortization: [Abstract]
Gross carrying amount		$ 759	$ 752
Accumulated amortization		416	363
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount		336	279
Gross carrying amount - other intangible assets		1,095	1,031
Land And Transmission Rights [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount		33	29
Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	[1]	303	250
Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[2]	407	408
Accumulated amortization	[2]	300	250
Land And Transmission Rights [Member]
Subject to amortization: [Abstract]
Gross carrying amount		337	329
Accumulated amortization		111	108
Emission Allowances And Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[3]	5	5
Accumulated amortization		0	0
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount		10	10
Accumulated amortization		5	5
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense		57	53	$ 57
Forecasted amortization in 2016		33
Forecasted amortization in 2017		15
Forecasted amortization in 2018		15
Forecasted amortization in 2019		15
Forecasted amortization in 2020		14
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		51	47	51
Forecasted amortization in 2016		27
Forecasted amortization in 2017		9
Forecasted amortization in 2018		9
Forecasted amortization in 2019		9
Forecasted amortization in 2020		8
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With No Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		6	6	6
Forecasted amortization in 2016		6
Forecasted amortization in 2017		6
Forecasted amortization in 2018		6
Forecasted amortization in 2019		6
Forecasted amortization in 2020		6
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount		320	312
Accumulated amortization		109	106
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets		353	341
PPL Electric Utilities Corp [Member] | Land And Transmission Rights [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount		33	29
PPL Electric Utilities Corp [Member] | Land And Transmission Rights [Member]
Subject to amortization: [Abstract]
Gross carrying amount		316	308
Accumulated amortization		108	105
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount		4	4
Accumulated amortization		1	1
LG And E And KU Energy LLC [Member]
Subject to amortization: [Abstract]
Gross carrying amount		419	419
Accumulated amortization		296	245
LG And E And KU Energy LLC [Member] | Coal Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[4]	269	269
Accumulated amortization	[4]	252	210
LG And E And KU Energy LLC [Member] | Land And Transmission Rights [Member]
Subject to amortization: [Abstract]
Gross carrying amount		21	21
Accumulated amortization		2	2
LG And E And KU Energy LLC [Member] | Emission Allowances [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[3]	3	3
Accumulated amortization		0	0
LG And E And KU Energy LLC [Member] | Ohio Valley Electric Corporation Power Purchase Agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[5]	126	126
Accumulated amortization	[5]	42	33
LG And E And KU Energy LLC [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense		51	47	52
LG And E And KU Energy LLC [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		51	47	51
Forecasted amortization in 2016		27
Forecasted amortization in 2017		9
Forecasted amortization in 2018		9
Forecasted amortization in 2019		9
Forecasted amortization in 2020		8
LG And E And KU Energy LLC [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With No Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		0	0	1
Louisville Gas And Electric Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount		219	219
Accumulated amortization		146	122
Louisville Gas And Electric Co [Member] | Coal Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[4]	124	124
Accumulated amortization	[4]	116	98
Louisville Gas And Electric Co [Member] | Land And Transmission Rights [Member]
Subject to amortization: [Abstract]
Gross carrying amount		7	7
Accumulated amortization		1	1
Louisville Gas And Electric Co [Member] | Emission Allowances [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[6]	1	1
Accumulated amortization		0	0
Louisville Gas And Electric Co [Member] | Ohio Valley Electric Corporation Power Purchase Agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[5]	87	87
Accumulated amortization	[5]	29	23
Louisville Gas And Electric Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		24	23	23
Forecasted amortization in 2016		14
Forecasted amortization in 2017		6
Forecasted amortization in 2018		6
Forecasted amortization in 2019		6
Forecasted amortization in 2020		6
Kentucky Utilities Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount		200	200
Accumulated amortization		150	123
Kentucky Utilities Co [Member] | Coal Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[4]	145	145
Accumulated amortization	[4]	136	112
Kentucky Utilities Co [Member] | Land And Transmission Rights [Member]
Subject to amortization: [Abstract]
Gross carrying amount		14	14
Accumulated amortization		1	1
Kentucky Utilities Co [Member] | Emission Allowances [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[3]	2	2
Accumulated amortization		0	0
Kentucky Utilities Co [Member] | Ohio Valley Electric Corporation Power Purchase Agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	[5]	39	39
Accumulated amortization	[5]	13	10
Kentucky Utilities Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense		27	24	29
Kentucky Utilities Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		27	24	28
Forecasted amortization in 2016		13
Forecasted amortization in 2017		3
Forecasted amortization in 2018		3
Forecasted amortization in 2019		3
Forecasted amortization in 2020		2
Kentucky Utilities Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With No Regulatory Offset [Member]
Subject to amortization: [Abstract]
Amortization expense		$ 0	$ 0	$ 1
[1]	Primarily from an increase in easements at WPD.
[2]	Gross carrying amount includes the fair value at the acquisition date of the OVEC power purchase contract and coal contracts with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL. Offsetting regulatory liabilities were recorded related to these contracts, which are being amortized over the same period as the intangible assets, eliminating any income statement impact. This is referred to as "regulatory offset" in the tables below. See Note 6 for additional information.
[3]	Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization.
[4]	Gross carrying amount r epresents the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition by PPL . An offsetting regulatory liability was recorded related to these contracts, which is being amortized over the same period as the intangible assets, eliminating any income statement impact. See Note 6 for additional information.
[5]	Gross carrying amount r epresents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 6 for additional inf ormation.
[6]	Emission allowances/RECs are expensed when consumed or sold; therefore, there i s no accumulated amortization.

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 336	$ 301
Accretion	19	16
Obligations incurred	5	1
Changes in estimated cash flow or settlement date	235	25
Effect of foreign currency exchange rates	(2)	(2)
Obligations settled	(7)	(5)
Balance at End of Period	586	336
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	285	252
Accretion	18	14
Obligations incurred	5	1
Changes in estimated cash flow or settlement date	234	23
Obligations settled	(7)	(5)
Balance at End of Period	535	285
Increase to the asset retirement obligation in connection with the final Coal Combustion Residual rule	228
Asset retirement obligation classified as current liabilities	50
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	74	74
Accretion	5	4
Changes in estimated cash flow or settlement date	98	1
Obligations settled	(5)	(5)
Balance at End of Period	175	74
Increase to the asset retirement obligation in connection with the final Coal Combustion Residual rule	89
Asset retirement obligation classified as current liabilities	25
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	211	178
Accretion	13	10
Obligations incurred	2	1
Changes in estimated cash flow or settlement date	136	22
Obligations settled	(2)	0
Balance at End of Period	360	$ 211
Increase to the asset retirement obligation in connection with the final Coal Combustion Residual rule	139
Asset retirement obligation classified as current liabilities	$ 25

Accumulated Other Comprehensi96

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (2,274)	$ (1,565)	$ (1,940)
Amounts arising during the period	(575)	(754)	323
Reclassifications from accumulated other comprehensive income	145	45	52
Net other comprehensive income during the period	(430)	(709)	375
Distribution of PPL Energy Supply	(24)
Balance at end of period	(2,728)	(2,274)	(1,565)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(286)	(11)	(149)
Amounts arising during the period	(234)	(275)	138
Reclassifications from accumulated other comprehensive income	0	0	0
Net other comprehensive income during the period	(234)	(275)	138
Distribution of PPL Energy Supply	0
Balance at end of period	(520)	(286)	(11)
Available For Sale Securities Unrealized Gains (Losses) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	201	172	111
Amounts arising during the period	8	35	67
Reclassifications from accumulated other comprehensive income	(2)	(6)	(6)
Net other comprehensive income during the period	6	29	61
Distribution of PPL Energy Supply	(207)
Balance at end of period	0	201	172
Qualifying Derivatives Unrealized Gains (Losses) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	20	94	132
Amounts arising during the period	26	(10)	45
Reclassifications from accumulated other comprehensive income	2	(64)	(83)
Net other comprehensive income during the period	28	(74)	(38)
Distribution of PPL Energy Supply	(55)
Balance at end of period	(7)	20	94
Equity Investees Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	1	1	1
Amounts arising during the period	0	0	0
Reclassifications from accumulated other comprehensive income	(1)	0	0
Net other comprehensive income during the period	(1)	0	0
Distribution of PPL Energy Supply	0
Balance at end of period	0	1	1
Defined Benefit Plans Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	3	(6)	(14)
Amounts arising during the period	(9)	5	2
Reclassifications from accumulated other comprehensive income	0	4	6
Net other comprehensive income during the period	(9)	9	8
Distribution of PPL Energy Supply	0
Balance at end of period	(6)	3	(6)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(2,213)	(1,815)	(2,021)
Amounts arising during the period	(366)	(509)	71
Reclassifications from accumulated other comprehensive income	146	111	135
Net other comprehensive income during the period	(220)	(398)	206
Distribution of PPL Energy Supply	238
Balance at end of period	(2,195)	(2,213)	(1,815)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period		13	(15)
Amounts arising during the period	(7)	(57)	28
Reclassifications from accumulated other comprehensive income	6	(1)
Net other comprehensive income during the period	(1)	(58)	28
Balance at end of period			13
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	1	1
Amounts arising during the period	0	0	0
Reclassifications from accumulated other comprehensive income	0	(1)
Net other comprehensive income during the period	0	(1)	0
Balance at end of period	0	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)	(2)	(2)
Amounts arising during the period	(3)	(7)	0
Reclassifications from accumulated other comprehensive income	1	1
Net other comprehensive income during the period	(2)	(6)	0
Balance at end of period	(10)	(8)	(2)
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	(37)	14	(14)
Amounts arising during the period	(4)	(50)	28
Reclassifications from accumulated other comprehensive income	5	(1)
Net other comprehensive income during the period	1	(51)	28
Balance at end of period	$ (36)	$ (37)	$ 14

Accumulated Other Comprehensi97

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Affected Line Item on the Statements of Income [Line Items]
Energy purchases																	$ (855)	$ (924)	$ (856)
Interest Expense																	(871)	(843)	(778)
Other Income (Expense) - net																	108	105	(55)
Total Pre-tax																	2,068	2,129	1,728
Income Taxes																	(465)	(692)	(360)
Total After-Tax	$ 405		$ 396		$ 250		$ 552		$ 408		$ 410		$ 230		$ 389		1,603	1,437	1,368
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-Tax																	(145)	(45)
Available For Sale Securities [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net																	4	13
Total Pre-tax																	4	13
Income Taxes																	(2)	(7)
Total After-Tax																	2	6
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax																	(17)	87
Income Taxes																	15	(23)
Total After-Tax																	(2)	64
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																	(11)	(16)
Discontinued operations																	(77)	0
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]
Interest Expense																	2	4
Other Income (Expense) - net																	49	57
Qualifying Derivatives [Member] | Commodity Contracts [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Discontinued operations																	20	42
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	0
Total Pre-tax																	1	0
Income Taxes																	0	0
Total After-Tax																	1	0
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																	(192)	(152)
Income Taxes																	46	37
Total After-Tax																	(146)	(115)
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																	0	(7)
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																	(192)	(145)
Kentucky Utilities Co [Member]
Affected Line Item on the Statements of Income [Line Items]
Energy purchases																	(18)	(23)	(22)
Interest Expense																	(82)	(77)	(70)
Other Income (Expense) - net																	1	(1)	(3)
Total Pre-tax																	374	355	360
Income Taxes																	$ (140)	$ (135)	$ (132)
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.

SCHEDULE I - CONDENSED UNCONS98

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Revenues [Abstract]
Operating Revenues	$ 1,780		$ 1,878		$ 1,781		$ 2,230		$ 1,946		$ 1,879		$ 1,849		$ 2,178		$ 7,669	$ 7,852	$ 7,263
Operating Expenses [Abstract]
Other operation and maintenance																	1,938	1,856	1,810
Total Operating Expenses																	4,838	4,985	4,702
Operating Income (Loss)	617		686		638		890		700		688		678		801		2,831	2,867	2,561
Other Income (Expense) - net [Abstract]
Other Income (Expense) - net																	108	105	(55)
Interest Expense																	871	843	778
Income (Loss) Before Income Taxes																	2,068	2,129	1,728
Income Tax Expense (Benefit)																	465	692	360
Net income	$ 399		$ 393		$ (757)	[2]	$ 647		$ 695	[3]	$ 497		$ 229		$ 316		682	1,737	1,130
Comprehensive Income (Loss)																	$ 252	$ 1,028	$ 1,505
Net Income Available to PPL Corporation Common Shareowners: (in dollars per share)
Basic	$ 0.59	[4]	$ 0.58	[4]	$ (1.13)	[4]	$ 0.97	[4]	$ 1.04	[4]	$ 0.74	[4]	$ 0.35	[4]	$ 0.5	[4]	$ 1.01	$ 2.64	$ 1.85
Diluted	$ 0.59	[4]	$ 0.58	[4]	$ (1.13)	[4]	$ 0.96	[4]	$ 1.04	[4]	$ 0.74	[4]	$ 0.34	[4]	$ 0.49	[4]	$ 1.01	$ 2.61	$ 1.76
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic																	669,814	653,504	608,983
Diluted																	672,586	665,973	663,073
PPL Corp [Member]
Operating Revenues [Abstract]
Operating Revenues																	$ 0	$ 0	$ 0
Operating Expenses [Abstract]
Other operation and maintenance																	9	16	1
Total Operating Expenses																	9	16	1
Operating Income (Loss)																	(9)	(16)	(1)
Other Income (Expense) - net [Abstract]
Equity in earnings of subsidiaries																	711	1,776	1,171
Other income (expense)																	(15)	(18)	(13)
Other Income (Expense) - net																	696	1,758	1,158
Interest Expense																	9	15	21
Interest Expense with Affiliates																	10	10	29
Income (Loss) Before Income Taxes																	668	1,717	1,107
Income Tax Expense (Benefit)																	(14)	(20)	(23)
Net income																	682	1,737	1,130
Comprehensive Income (Loss)																	$ 252	$ 1,028	$ 1,505
Net Income Available to PPL Corporation Common Shareowners: (in dollars per share)
Basic																	$ 1.01	$ 2.64	$ 1.85
Diluted																	$ 1.01	$ 2.61	$ 1.76
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic																	669,814	653,504	608,983
Diluted																	672,586	665,973	663,073
L G And E And K U Energy L L C Unconsolidated [Member]
Other Income (Expense) - net [Abstract]
Equity in earnings of subsidiaries																	$ 390	$ 368	$ 376
Interest Income from Affiliates																	4	5	5
Interest Expense																	39	41	39
Interest Expense with Affiliates																	5	3	3
Income (Loss) Before Income Taxes																	350	329	339
Income Tax Expense (Benefit)																	(14)	(15)	(8)
Net income																	364	344	347
Comprehensive Income (Loss)																	$ 363	$ 286	$ 375
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.
[2]	The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information.
[3]	(f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
[4]	The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.

SCHEDULE I - CONDENSED UNCONS99

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash Flows from Operating Activities [Abstact]
Net cash provided by (used in) operating activities	$ 2,272	$ 2,941	$ 2,447
Cash Flows from Investing Activities [Abstact]
Net cash provided by (used in) investing activities	(3,439)	(3,826)	(3,664)
Cash Flows from Financing Activities [Abstract]
Issuance of equity, net of issuance costs	203	1,074	1,411
Net increase (decrease) in short-term debt	94	147	405
Retirement of long-term debt	(1,000)	(237)	0
Issuance of long-term debt	2,236	296	2,038
Payment of common stock dividends	(1,004)	(967)	(878)
Contract adjustment payments on Equity Units	0	(22)	(82)
Repurchase of common stock	0	0	(74)
Other	(47)	(29)	(67)
Net cash provided by (used in) financing activities	482	262	2,753
Net Increase (Decrease) in Cash and Cash Equivalents	(563)	536	375
Cash and Cash Equivalents at Beginning of Period	1,399	863	488
Cash and Cash Equivalents at End of Period	836	1,399	863
PPL Corp [Member]
Cash Flows from Operating Activities [Abstact]
Net cash provided by (used in) operating activities	993	1,633	968
Cash Flows from Investing Activities [Abstact]
Capital contributions to affiliated subsidiaries	(491)	(1,045)	(496)
Return of capital from affiliated subsidiaries	112	247	213
Net cash provided by (used in) investing activities	(379)	(798)	(283)
Cash Flows from Financing Activities [Abstract]
Issuance of equity, net of issuance costs	203	1,074	1,411
Net increase (decrease) in debt with affiliates	215	(913)	(1,057)
Payment of common stock dividends	(1,004)	(967)	(878)
Contract adjustment payments on Equity Units	0	(22)	(82)
Repurchase of common stock	0	0	(74)
Other	(28)	(7)	(5)
Net cash provided by (used in) financing activities	(614)	(835)	(685)
Cash and Cash Equivalents at Beginning of Period	0	0	0
Cash and Cash Equivalents at End of Period	0	0	0
Supplemental Disclosures of Cash Flow Information: [Abstract]
Cash Dividends Received from Affiliated Subsidiaries	1,198	1,388	960
L G And E And K U Energy L L C Unconsolidated [Member]
Cash Flows from Operating Activities [Abstact]
Net cash provided by (used in) operating activities	246	(183)	136
Cash Flows from Investing Activities [Abstact]
Capital contributions to affiliated subsidiaries	140	248	(243)
Net (increase) decrease in notes receivable from affiliates	73	555	(122)
Net cash provided by (used in) investing activities	(67)	307	(365)
Cash Flows from Financing Activities [Abstract]
Net increase (decrease) in notes payable to affiliates	315	58	171
Net increase (decrease) in short-term debt	0	0	75
Retirement of long-term debt	(400)	0	0
Contributions from member	125	248	243
Distributions to member	(219)	(436)	(254)
Net cash provided by (used in) financing activities	(179)	(130)	235
Net Increase (Decrease) in Cash and Cash Equivalents	0	(6)	6
Cash and Cash Equivalents at Beginning of Period	0	6	0
Cash and Cash Equivalents at End of Period	0	0	6
Supplemental Disclosures of Cash Flow Information: [Abstract]
Cash Dividends Received from Affiliated Subsidiaries	$ 272	$ 260	$ 223

SCHEDULE I - CONDENSED UNCON100

SCHEDULE I - CONDENSED UNCONSOLIDATED BALANCE SHEETS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current Assets
Cash and cash equivalents		$ 836	$ 1,399	$ 863	$ 488
Accounts Receivable [Abstract]
Other		59	71
Accounts receivable		673	737
Prepayments		66	75
Price risk management assets		139	79
Other current assets		63	55
Total Current Assets		2,646	6,026
Other Noncurrent Assets [Abstract]
Other noncurrent assets		311	203
Total Other Noncurrent Assets		6,273	14,411
Total Assets		39,301	48,606
Current Liabilities [Abstract]
Short-term debt		916	836
Long-term debt due within one year		485	1,000
Dividends		255	249
Taxes		85	263
Other current liabilities		549	632
Total Current Liabilities		3,876	7,439
Long-term Debt [Abstract]
Total Long-term Debt		18,563	17,054
Total Deferred Credits and Other Noncurrent Liabilities		6,943	10,485
Equity [Abstract]
Common stock	[1]	7	7
Additional paid-in capital		9,687	9,433
Earnings reinvested		2,953	6,462
Accumulated other comprehensive income (loss)		(2,728)	(2,274)	(1,565)	(1,940)
Total Equity		9,919	13,628	12,466	10,498
Total Liabilities and Equity		$ 39,301	$ 48,606
PPL Corporation Shareowners' Common Equity Additional Information [Abstract]
Common stock par value		$ 0.01	$ 0.01
Common stock shares authorized		780,000	780,000
Common stock shares issued		673,857	665,849
Common stock shares outstanding		673,857	665,849
PPL Corp [Member]
Current Assets
Cash and cash equivalents		$ 0	$ 0	0	0
Accounts Receivable [Abstract]
Other		10	53
Accounts receivable from affiliates		20	149
Price risk management assets		139	148
Total Current Assets		169	350
Investments [Abstract]
Affiliated companies at equity		10,479	15,426
Other Noncurrent Assets [Abstract]
Deferred income taxes		100	34
Price risk management assets		133	75
Other noncurrent assets		1	13
Total Other Noncurrent Assets		234	122
Total Assets		10,882	15,898
Current Liabilities [Abstract]
Short-term debt with affiliates		385	170
Accounts payable to affiliates		16	1,513
Dividends		255	249
Price risk management liabilities		268	227
Other current liabilities		0	65
Total Current Liabilities		924	2,224
Long-term Debt [Abstract]
Total Deferred Credits and Other Noncurrent Liabilities		39	46
Equity [Abstract]
Common stock	[1]	7	7
Additional paid-in capital		9,687	9,433
Earnings reinvested		2,953	6,462
Accumulated other comprehensive income (loss)		(2,728)	(2,274)
Total Equity		9,919	13,628
Total Liabilities and Equity		$ 10,882	$ 15,898
PPL Corporation Shareowners' Common Equity Additional Information [Abstract]
Common stock par value		$ 0.01	$ 0.01
Common stock shares authorized		780,000	780,000
Common stock shares issued		673,857	665,849
Common stock shares outstanding		673,857	665,849
L G And E And K U Energy L L C Unconsolidated [Member]
Current Assets
Cash and cash equivalents		$ 0	$ 0	$ 6	$ 0
Accounts Receivable [Abstract]
Accounts receivable		1	8
Accounts receivable from affiliates		3	0
Notes receivable from affiliates		1,054	1,127
Total Current Assets		1,058	1,135
Investments [Abstract]
Affiliated companies at equity		5,076	4,818
Other Noncurrent Assets [Abstract]
Deferred income taxes		228	205
Other noncurrent assets		0	1
Total Other Noncurrent Assets		228	206
Total Assets		6,362	6,159
Current Liabilities [Abstract]
Short-term debt		75	75
Notes payable to affiliates		69	58
Long-term debt due within one year		0	400
Accounts payable to affiliates		469	451
Taxes		3	2
Other current liabilities		5	8
Total Current Liabilities		621	994
Long-term Debt [Abstract]
Long-term debt		720	718
Notes payable to affiliates		500	196
Total Long-term Debt		1,220	914
Total Deferred Credits and Other Noncurrent Liabilities		4	3
Equity [Abstract]
Members Equity		4,517	4,248
Total Liabilities and Equity		$ 6,362	$ 6,159
[1]	780,000 shares authorized; 673,857 and 665,849 shares issued and outstanding at December 31, 2015 and 2014 .

SCHEDULE I - NOTES TO CONDENSED

SCHEDULE I - NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Aggregate maturities of long-term debt (Details) [Abstract]
2,020		$ 1,301
Principal outstanding		19,171	$ 18,188
New Accounting Pronouncement Early Adoption [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Deferred tax assets			125
Deferred tax liabilities			0
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Maximum exposure	[1]	$ 301
Term of guarantee (in years)		12
Expiration date minimum		2,021
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues		$ 200
Maximum exposure of other guarantees expiring related to a terminated lease		$ 100
Expiration date maximum		2,023
PPL Corp [Member] | New Accounting Pronouncement Early Adoption [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Deferred tax assets			34
Deferred tax liabilities			5
PPL Corp [Member] | PPL Guarantee [Member] | Financial Guarantee [Member] | Guarantee Of Principal And Premium And Interest [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Maximum exposure		$ 8,400
Expiration date		2,073
LG&E and KU Energy LLC Unconsolidated | New Accounting Pronouncement Early Adoption [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Deferred tax assets			2
Debt issuance costs reclassed from other noncurrent assets to long-term debt			$ 4
LG&E and KU Energy LLC Unconsolidated | Senior Unsecured Notes [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
2,020		$ 475
2,021		250
LG&E and KU Energy LLC Unconsolidated | Note Payable [Member] | PPL [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Principal outstanding		$ 400
Maturity date (in years)		Dec. 31, 2025
LG&E and KU Energy LLC Unconsolidated | Note Payable [Member] | LGE [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Principal outstanding		$ 100
Maturity date (in years)		Dec. 31, 2019
Stated interest rate		1.068%
LG&E and KU Energy LLC Unconsolidated | Note Payable [Member] | KU [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Principal outstanding		$ 100
Maturity date (in years)		Dec. 31, 2019
Stated interest rate		1.068%
LG&E and KU Energy LLC Unconsolidated | LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Term of guarantee (in years)		12
Expiration date minimum		2,021
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues		$ 200
Maximum exposure of other guarantees expiring related to a terminated lease		$ 100
Expiration date maximum		2,023
[1]	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 fall outside the cap. Another WKE-related LKE guarantee covers other indemnifications related to the p urchase 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 Oct ober 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. LKE does not believe appropriate contractual, legal or commercial grounds exist for the claim s made and has disputed the demand s . LKE believes its indemnification obligations in the WKE matter remain subject to various uncertain ties, including additional legal and contractual developments, as well as future prices, availability and demand for the subject excess power. The parties are conducting preliminary settlement discussions, however, the ultimate outcomes of the WKE termina tion-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 ou tcomes of the indemnification circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded.

Quarterly Financial Data (Un102

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended		3 Months Ended																12 Months Ended
		Nov. 30, 2015	Nov. 30, 2014	Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015		Mar. 31, 2015		Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues				$ 1,780	[1]	$ 1,878	[1]	$ 1,781	[1]	$ 2,230	[1]	$ 1,946	[1]	$ 1,879	[1]	$ 1,849	[1]	$ 2,178	[1]	$ 7,669		$ 7,852		$ 7,263
Operating income				617	[1]	686	[1]	638	[1]	890	[1]	700	[1]	688	[1]	678	[1]	801	[1]	2,831		2,867		2,561
Income from continuing operations after income taxes				405	[1]	396	[1]	250	[1]	552	[1]	408	[1]	410	[1]	230	[1]	389	[1]	1,603		1,437		1,368
Income (Loss) from Discontinued Operations (net of income taxes)				(6)	[1]	(3)	[1]	(1,007)	[1],[2],[3]	95	[1],[2]	287	[1],[2],[4]	87	[1],[2]	(1)	[1],[2]	(73)	[1],[2]	(921)		300		(238)
Net income (loss)				$ 399	[1]	$ 393	[1]	$ (757)	[1],[3]	$ 647	[1]	$ 695	[1],[4]	$ 497	[1]	$ 229	[1]	$ 316	[1]	$ 682		$ 1,737		$ 1,130
Income from continuing operations after income taxes available to PPL common shareowners: [Abstract]
Basic (in dollars per share)				$ 0.6	[1],[5]	$ 0.59	[1],[5]	$ 0.37	[1],[5]	$ 0.83	[1],[5]	$ 0.62	[1],[5]	$ 0.61	[1],[5]	$ 0.35	[1],[5]	$ 0.61	[1],[5]	$ 2.38		$ 2.19		$ 2.24
Diluted (in dollars per share)				0.6	[1],[5]	0.59	[1],[5]	0.37	[1],[5]	0.82	[1],[5]	0.62	[1],[5]	0.61	[1],[5]	0.34	[1],[5]	0.61	[1],[5]	2.37		2.16		2.12
Net income (loss) available to PPL common shareowners: [Abstract]
Basic (in dollars per share)				0.59	[1],[5]	0.58	[1],[5]	(1.13)	[1],[5]	0.97	[1],[5]	1.04	[1],[5]	0.74	[1],[5]	0.35	[1],[5]	0.5	[1],[5]	1.01		2.64		1.85
Diluted (in dollars per share)				0.59	[1],[5]	0.58	[1],[5]	(1.13)	[1],[5]	0.96	[1],[5]	1.04	[1],[5]	0.74	[1],[5]	0.34	[1],[5]	0.49	[1],[5]	1.01		2.61		1.76
Dividends declared per share of common stock (in dollars per share)		$ 0.3775		0.3775	[1],[6]	0.3775	[1],[6]	0.3725	[1],[6]	0.3725	[1],[6]	0.3725	[1],[6]	0.3725	[1],[6]	0.3725	[1],[6]	0.3725	[1],[6]	$ 1.5		$ 1.49		$ 1.47
Price per common share: [Abstract]
High (in dollars per share)	[1]			34.75		33.58		34.85		36.38		38.14		35.52		35.56		33.24
Low (in dollars per share)	[1]			$ 32.6		$ 29.41		$ 29.45		$ 31.4		$ 32.09		$ 31.79		$ 32.32		$ 29.4
PPL Energy Supply Spinoff [Member]
Quarterly Financial Information Disclosure [Line Items]
Income (Loss) from Discontinued Operations (net of income taxes)																				$ (921)		$ 300		$ (238)
Price per common share: [Abstract]
Gain (loss) on disposal group								$ 879												(879)		0		0
Montana Hydroelectric Generating Facilities [Member]
Price per common share: [Abstract]
Gain (loss) on disposal group			$ 137									$ 137
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues				$ 499	[7]	$ 519	[7]	476	[7]	$ 630	[7]	526	[7]	$ 477	[7]	$ 449	[7]	$ 592	[7]	2,124		2,044		1,870
Operating income				126	[7]	121	[7]	116	[7]	175	[7]	138	[7]	124	[7]	111	[7]	165	[7]	538		538		419
Net income (loss)				$ 61	[7]	$ 55	[7]	$ 49	[7]	$ 87	[7]	$ 69	[7]	$ 57	[7]	$ 52	[7]	$ 85	[7]	$ 252	[8]	$ 263	[8]	$ 209	[8]
[1]	Quarterly results can vary depending on, among other things, weather . Accordingly, comparisons among quarters of a year may not be indicative of overall tr ends and changes in operations.
[2]	In the second quarter of 2015, PPL completed the spinoff of PPL Energy Supply sub stantially representing PPL's Supply segment. Accordingly, the previously reported operating results for PPL’s Supply segment have been reclassified as discontinued operations. See Note 8 to the Financial Statements for additional information.
[3]	The second quarter of 2015 includes a loss of $879 million from the spinoff of PPL Energy Supply. See Note 8 to the Financial Statements for additional information.
[4]	(f) The fourth quarter of 2014 includes a gain of $137 million (after-tax) from the sale of Hydroelectric generating facilities of PPL Montana. See Note 8 for additional information.
[5]	The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.
[6]	PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future d ividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.
[7]	PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.
[8]	Net income approximates comprehensive income.