Talen Energy Supply 10-K 24 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jan. 31, 2014	Jun. 28, 2013
Document Entity Information [Line Items]	'	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Entity Registrant Name	'PPL Corp	'	'
Entity Central Index Key	'0000922224	'	'
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	'	'	$17,902,483,657
Entity Common Stock, Shares Outstanding	'	630,716,792	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
PPL Energy Supply LLC [Member]	'	'	'
Document Entity Information [Line Items]	'	'	'
Amendment Flag	'false	'	'
Entity Registrant Name	'PPL ENERGY SUPPLY LLC	'	'
Entity Central Index Key	'0001161976	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
PPL Electric Utilities Corp [Member]	'	'	'
Document Entity Information [Line Items]	'	'	'
Amendment Flag	'false	'	'
Entity Registrant Name	'PPL ELECTRIC UTILITIES CORP	'	'
Entity Central Index Key	'0000317187	'	'
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	'0001518339	'	'
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	'0000060549	'	'
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	'0000055387	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	37,817,878	'

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	12 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Operating Revenues	'		'		'
Utility	$7,201		$6,808		$6,292
Unregulated wholesale energy	3,044		4,126		5,212
Unregulated retail energy	1,027		844		726
Energy-related businesses	588		508		507
Total Operating Revenues	11,860		12,286		12,737
Operation	'		'		'
Fuel	1,944		1,837		1,946
Energy purchases	1,967		2,555		3,253
Other operation and maintenance	2,825		2,835		2,667
Loss on lease termination	697		'		'
Depreciation	1,161		1,100		960
Taxes, other than income	364		366		326
Energy-related businesses	563		484		484
Total Operating Expenses	9,521		9,177		9,636
Operating Income (Loss)	2,339		3,109		3,101
Other Income (Expense) - net	-23		-39		4
Other-Than-Temporary Impairments	1		27		6
Interest Expense	1,006		961		898
Income (Loss) Before Income Taxes	1,309		2,082		2,201
Income Taxes	180		545		691
Income (Loss) from Continuing Operations After Income Taxes	1,129		1,537		1,510
Income (Loss) from Discontinued Operations (net of income taxes)	2		-6		2
Net Income (Loss)	1,131		1,531		1,512
Net Income (Loss) Attributable to Noncontrolling Interests	1		5		17
Net Income (Loss) Attributable to Shareowners	1,130		1,526		1,495
Amounts Attributable to Shareowners:	'		'		'
Income from Continuing Operations After Income Taxes	1,128		1,532		1,493
Income (Loss) from Discontinued Operations (net of income taxes)	2		-6		2
Net Income (Loss)	1,130		1,526		1,495
Income from Continuing Operations After Income Taxes Available to PPL Common Shareowners:	'		'		'
Basic (in dollars per share)	$1.85		$2.62		$2.70
Diluted (in dollars per share)	$1.76		$2.61		$2.70
Net Income Available to PPL Common Shareowners:	'		'		'
Basic (in dollars per share)	$1.85		$2.61		$2.71
Diluted (in dollars per share)	$1.76		$2.60		$2.70
Dividends Declared Per Share of Common Stock	$1.47		$1.44		$1.40
Weighted-Average Shares of Common Stock Outstanding (in thousands)	'		'		'
Basic	608,983		580,276		550,395
Diluted	663,073		581,626		550,952
PPL Energy Supply LLC [Member]	'		'		'
Operating Revenues	'		'		'
Unregulated wholesale energy	3,044		4,126		5,212
Unregulated retail energy	1,031		848		727
Revenue to affiliates	51		78		26
Energy-related businesses	527		448		464
Total Operating Revenues	4,653		5,500		6,429
Operation	'		'		'
Fuel	1,049		965		1,080
Energy purchases	1,168		1,818		2,283
Energy purchases from affiliates	3		3		3
Other operation and maintenance	1,072		1,041		929
Loss on lease termination	697		'		'
Depreciation	318		285		244
Taxes, other than income	66		69		71
Energy-related businesses	512		432		458
Total Operating Expenses	4,885		4,613		5,068
Operating Income (Loss)	-232		887		1,361
Other Income (Expense) - net	30		18		23
Other-Than-Temporary Impairments	1		1		6
Interest Income from Affiliates	3		2		8
Interest Expense	171		168		174
Income (Loss) Before Income Taxes	-371		738		1,212
Income Taxes	-142	[1]	263	[1]	445	[1]
Income (Loss) from Continuing Operations After Income Taxes	-229		475		767
Income (Loss) from Discontinued Operations (net of income taxes)	'		'		2
Net Income (Loss)	-229		475		769
Net Income (Loss) Attributable to Noncontrolling Interests	1		1		1
Net Income (Loss) Attributable to Shareowners	-230		474		768
Amounts Attributable to Shareowners:	'		'		'
Income from Continuing Operations After Income Taxes	-230		474		766
Income (Loss) from Discontinued Operations (net of income taxes)	'		'		2
Net Income (Loss)	-230		474		768
PPL Electric Utilities Corp [Member]	'		'		'
Operating Revenues	'		'		'
Retail electric	1,866		1,760		1,881
Revenue to affiliates	4		3		11
Total Operating Revenues	1,870		1,763		1,892
Operation	'		'		'
Energy purchases - realized	588		550		738
Energy purchases from affiliates	51		78		26
Other operation and maintenance	531		576		530
Depreciation	178		160		146
Taxes, other than income	103		105		104
Total Operating Expenses	1,451		1,469		1,544
Operating Income (Loss)	419		294		348
Other Income (Expense) - net	6		9		7
Interest Expense	108		99		98
Income (Loss) Before Income Taxes	317		204		257
Income Taxes	108		68		68
Net Income (Loss)	209	[2]	136	[2]	189	[2]
Distributions on Preferred Securities	'		4		16
Net Income Available to PPL	209		132		173
LG And E And KU Energy LLC [Member]	'		'		'
Operating Revenues	'		'		'
Total Operating Revenues	2,976		2,759		2,793
Operation	'		'		'
Fuel	896		872		866
Energy purchases - realized	217		195		238
Other operation and maintenance	778		778		751
Depreciation	334		346		334
Taxes, other than income	48		46		37
Total Operating Expenses	2,273		2,237		2,226
Operating Income (Loss)	703		522		567
Other Income (Expense) - net	-7		-15		-1
Other-Than-Temporary Impairments	'		25		'
Interest Expense	144		150		146
Interest Expense with Affiliates	1		1		1
Income (Loss) Before Income Taxes	551		331		419
Income Taxes	206	[3]	106	[3]	153	[3]
Income (Loss) from Continuing Operations After Income Taxes	345		225		266
Income (Loss) from Discontinued Operations (net of income taxes)	2		-6		-1
Net Income (Loss)	347		219		265
Louisville Gas And Electric Co [Member]	'		'		'
Operating Revenues	'		'		'
Utility	1,351		1,247		1,281
Revenue to affiliates	59		77		83
Total Operating Revenues	1,410		1,324		1,364
Operation	'		'		'
Fuel	367		374		350
Energy purchases - realized	195		163		209
Energy purchases from affiliates	10		12		36
Other operation and maintenance	373		363		363
Depreciation	148		152		147
Taxes, other than income	24		23		18
Total Operating Expenses	1,117		1,087		1,123
Operating Income (Loss)	293		237		241
Other Income (Expense) - net	-2		-3		-2
Interest Expense	34		42		44
Income (Loss) Before Income Taxes	257		192		195
Income Taxes	94		69		71
Net Income (Loss)	163		123		124
Kentucky Utilities Co [Member]	'		'		'
Operating Revenues	'		'		'
Utility	1,625		1,512		1,512
Revenue to affiliates	10		12		36
Total Operating Revenues	1,635		1,524		1,548
Operation	'		'		'
Fuel	529		498		516
Energy purchases - realized	22		32		29
Energy purchases from affiliates	59		77		83
Other operation and maintenance	382		384		362
Depreciation	186		193		186
Taxes, other than income	24		23		19
Total Operating Expenses	1,202		1,207		1,195
Operating Income (Loss)	433		317		353
Other Income (Expense) - net	-3		-8		-1
Other-Than-Temporary Impairments	'		25		'
Interest Expense	70		69		70
Income (Loss) Before Income Taxes	360		215		282
Income Taxes	132	[4]	78	[4]	104	[4]
Net Income (Loss)	$228		$137		$178
[1]	Excludes current and deferred federal, state and foreign tax expense (benefit) recorded to Discontinued Operations of $3 million in 2011. Also, excludes federal, state and foreign tax expense (benefit) recorded to OCI of $47 million in 2013, $(267) million in 2012 and $(83) million in 2011. The deferred tax benefit of operating loss carryforwards was insignificant for 2011.
[2]	Net income approximates comprehensive income.
[3]	Excludes current and deferred federal and state tax expense (benefit) recorded to Discontinued Operations of $1 million in 2013, $(4) million in 2012, and $(1) million in 2011. Also, excludes deferred federal and state tax expense (benefit) recorded to OCI of $18 million in 2013, $(12) million in 2012 and $(1) million in 2011.
[4]	Excludes deferred federal and state tax (benefit) recorded to OCI of less than $1 million in 2013 and $1 million in 2012.

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net income (loss)	$1,131		$1,531		$1,512
Amounts arising during the period - gains (losses), net of tax (expense) benefit:	'		'		'
Foreign currency translation adjustments, net of tax	138		94		-48
Available-for-sale securities, net of tax	67		29		9
Qualifying derivatives, net of tax	45		39		202
Equity investees' other comprehensive income (loss), net of tax	'		2		'
Defined benefit plans:	'		'		'
Prior service costs, net of tax	2		1		-3
Net actuarial gain (loss), net of tax	71		-965		-152
Reclassifications to net income - (gains) losses, net of tax expense (benefit):	'		'		'
Available-for-sale securities, net of tax	-6		-7		-7
Qualifying derivatives, net of tax	-83		-434		-370
Equity investee's other comprehensive (income) loss, net of tax	'		'		3
Defined benefit plans:	'		'		'
Prior service costs, net of tax	6		10		10
Net actuarial loss, net of tax	135		79		47
Total other comprehensive income (loss)	375		-1,152		-309
Comprehensive income (loss)	1,506		379		1,203
Comprehensive income attributable to noncontrolling interests	1		5		17
Comprehensive income (loss) attributable to Shareowners	1,505		374		1,186
PPL Energy Supply LLC [Member]	'		'		'
Net income (loss)	-229		475		769
Amounts arising during the period - gains (losses), net of tax (expense) benefit:	'		'		'
Available-for-sale securities, net of tax	67		29		9
Qualifying derivatives, net of tax	'		68		267
Defined benefit plans:	'		'		'
Prior service costs, net of tax	2		1		-2
Net actuarial gain (loss), net of tax	71		-82		-22
Reclassifications to net income - (gains) losses, net of tax expense (benefit):	'		'		'
Available-for-sale securities, net of tax	-6		-7		-7
Qualifying derivatives, net of tax	-123		-463		-353
Equity investee's other comprehensive (income) loss, net of tax	'		'		3
Defined benefit plans:	'		'		'
Prior service costs, net of tax	4		5		4
Net actuarial loss, net of tax	14		10		4
Total other comprehensive income (loss)	29		-439		-97
Comprehensive income (loss)	-200		36		672
Comprehensive income attributable to noncontrolling interests	1		1		1
Comprehensive income (loss) attributable to Shareowners	-201		35		671
PPL Electric Utilities Corp [Member]	'		'		'
Net income (loss)	209	[1]	136	[1]	189	[1]
LG And E And KU Energy LLC [Member]	'		'		'
Net income (loss)	347		219		265
Amounts arising during the period - gains (losses), net of tax (expense) benefit:	'		'		'
Equity investees' other comprehensive income (loss), net of tax	'		1		'
Defined benefit plans:	'		'		'
Prior service costs, net of tax	'		'		-2
Net actuarial gain (loss), net of tax	28		-21		'
Defined benefit plans:	'		'		'
Net actuarial loss, net of tax	'		1		'
Total other comprehensive income (loss)	28		-19		-2
Comprehensive income (loss) attributable to Shareowners	375		200		263
Louisville Gas And Electric Co [Member]	'		'		'
Net income (loss)	163		123		124
Kentucky Utilities Co [Member]	'		'		'
Net income (loss)	228		137		178
Defined benefit plans:	'		'		'
Total other comprehensive income (loss)	'		$1		'
[1]	Net income approximates comprehensive income.

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Tax effect of foreign currency translation adjustments arising during the period	$4	$2	($2)
Tax effect of available-for-sale securities arising during the period	-72	-31	-6
Tax effect of qualifying derivatives arising during the period	-41	-32	-139
Tax effect of equity investees' other comprehensive income (loss) arising during the period	0	-1	0
Tax effect of defined benefit plans - prior service costs arising during period	-1	0	-1
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	-73	343	58
Tax effect of available-for-sale securities reclassified to net income	4	1	5
Tax effect of qualifying derivatives reclassified to net income	80	278	246
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	-4	-5	-5
Tax effect of net actuarial loss reclassified to net income	49	29	19
PPL Energy Supply LLC [Member]	'	'	'
Tax effect of available-for-sale securities arising during the period	-72	-31	-6
Tax effect of qualifying derivatives arising during the period	0	-46	-164
Tax effect of defined benefit plans - prior service costs arising during period	-1	0	-2
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	-49	56	13
Tax effect of available-for-sale securities reclassified to net income	4	1	5
Tax effect of qualifying derivatives reclassified to net income	84	291	242
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	-3	-2	-3
Tax effect of net actuarial loss reclassified to net income	10	2	2
LG And E And KU Energy LLC [Member]	'	'	'
Tax effect of equity investees' other comprehensive income (loss) arising during the period	0	-1	0
Tax effect of defined benefit plans - prior service costs arising during period	0	0	1
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	-18	13	-1
Tax effect of net actuarial loss reclassified to net income	$0	$0	$1

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Cash Flows from Operating Activities	'		'		'
Net income (loss)	$1,131		$1,531		$1,512
Adjustments to reconcile net income to net cash provided by (used in) operating activities	'		'		'
Depreciation	1,161		1,100		961
Amortization	222		186		254
Defined benefit plans - expense	176		166		205
Deferred income taxes and investment tax credits	72		424		582
Impairment of assets	65		28		13
Unrealized (gains) losses on derivatives, and other hedging activities	236		27		-314
Loss on lease termination	426		'		'
Other	80		-27		-38
Change in current assets and current liabilities	'		'		'
Accounts receivable	-165		7		-89
Accounts payable	25		-29		-36
Unbilled revenues	27		-19		64
Prepayments	14		-5		294
Counterparty collateral	-81		-34		-190
Taxes payable	20		24		-104
Regulatory assets and liabilities	18		-2		106
Unrecognized tax positions	-114		-4		6
Accrued interest	-3		32		109
Other	-91		12		'
Other operating activities	'		'		'
Defined benefit plans - funding	-563		-607		-667
Other assets	7		-33		-62
Other liabilities	194		-13		-99
Net cash provided by (used in) operating activities	2,857		2,764		2,507
Cash Flows from Investing Activities	'		'		'
Expenditures for property, plant and equipment	-4,212		-3,105		-2,487
Proceeds from the sale of certain non-core generation facilities	'		'		381
Ironwood Acquisition, net of cash acquired	'		-84		'
Acquisition of WPD Midlands	'		'		-5,763
Expenditures for intangible assets	-95		-71		-102
Purchases of nuclear plant decommissioning trust investments	-159		-154		-169
Proceeds from the sale of nuclear plant decommissioning trust investments	144		139		156
Proceeds from the sale of other investments	'		20		163
Net (increase) decrease in restricted cash and cash equivalents	-20		96		-143
Other investing activities	47		36		12
Net cash provided by (used in) investing activities	-4,295		-3,123		-7,952
Cash Flows from Financing Activities	'		'		'
Issuance of long-term debt	2,038		1,223		5,745
Retirement of long-term debt	-747		-108		-1,210
Repurchase of common stock	-74		'		'
Issuance of common stock	1,411		72		2,297
Payment of common stock dividends	-878		-833		-746
Redemption of preference stock of a subsidiary	'		-250		'
Debt issuance and credit facility costs	-49		-17		-102
Contract adjustment payments	-82		-94		-72
Net increase (decrease) in short-term debt	49		74		-125
Other financing activities	-37		-19		-20
Net cash provided by (used in) financing activities	1,631		48		5,767
Effect of Exchange Rates on Cash and Cash Equivalents	8		10		-45
Net Increase (Decrease) in Cash and Cash Equivalents	201		-301		277
Cash and Cash Equivalents at Beginning of Period	901		1,202		925
Cash and Cash Equivalents at End of Period	1,102		901		1,202
Supplemental Disclosures of Cash Flow Information:	'		'		'
Interest - net of amount capitalized	916		847		696
Income taxes - net	128		73		-76
PPL Energy Supply LLC [Member]	'		'		'
Cash Flows from Operating Activities	'		'		'
Net income (loss)	-229		475		769
Adjustments to reconcile net income to net cash provided by (used in) operating activities	'		'		'
Depreciation	318		285		245
Amortization	156		119		137
Defined benefit plans - expense	51		43		36
Deferred income taxes and investment tax credits	-296		152		317
Impairment of assets	65		3		13
Unrealized (gains) losses on derivatives, and other hedging activities	171		-41		-283
Loss on lease termination	426		'		'
Other	2		19		-65
Change in current assets and current liabilities	'		'		'
Accounts receivable	23		-54		38
Accounts payable	-56		-22		-73
Unbilled revenues	83		33		14
Fuel, materials and supplies	-31		-29		-10
Counterparty collateral	-81		-34		-190
Taxes payable	-31		-27		27
Other	-14		-39		-8
Other operating activities	'		'		'
Defined benefit plans - funding	-113		-75		-152
Other assets	-4		-41		-30
Other liabilities	-30		17		-9
Net cash provided by (used in) operating activities	410		784		776
Cash Flows from Investing Activities	'		'		'
Expenditures for property, plant and equipment	-583		-648		-661
Proceeds from the sale of certain non-core generation facilities	'		'		381
Ironwood Acquisition, net of cash acquired	'		-84		'
Expenditures for intangible assets	-42		-45		-57
Purchases of nuclear plant decommissioning trust investments	-159		-154		-169
Proceeds from the sale of nuclear plant decommissioning trust investments	144		139		156
Net (increase) decrease in notes receivable from affiliates	'		198		-198
Net (increase) decrease in restricted cash and cash equivalents	-22		104		-128
Other investing activities	31		21		8
Net cash provided by (used in) investing activities	-631		-469		-668
Cash Flows from Financing Activities	'		'		'
Issuance of long-term debt	'		'		500
Retirement of long-term debt	-747		-9		-750
Contributions from member	1,577		563		461
Distributions to member	-408		-787		-316
Cash included in net assets of subsidiary distributed to member	'		'		-325
Net increase (decrease) in short-term debt	-356		-44		50
Other financing activities	-19		-4		-10
Net cash provided by (used in) financing activities	47		-281		-390
Net Increase (Decrease) in Cash and Cash Equivalents	-174		34		-282
Cash and Cash Equivalents at Beginning of Period	413		379		661
Cash and Cash Equivalents at End of Period	239		413		379
Supplemental Disclosures of Cash Flow Information:	'		'		'
Interest - net of amount capitalized	157		150		165
Income taxes - net	189		128		69
PPL Electric Utilities Corp [Member]	'		'		'
Cash Flows from Operating Activities	'		'		'
Net income (loss)	209	[1]	136	[1]	189	[1]
Adjustments to reconcile net income to net cash provided by (used in) operating activities	'		'		'
Depreciation	178		160		146
Amortization	19		18		8
Defined benefit plans - expense	21		22		18
Deferred income taxes and investment tax credits	127		114		106
Other	-9		-9		-7
Change in current assets and current liabilities	'		'		'
Accounts receivable	-29		3		-5
Accounts payable	12		38		-60
Unbilled revenues	-6		-8		36
Prepayments	36		2		58
Taxes payable	49		12		-23
Regulatory assets and liabilities	19		-1		107
Other	-28		-5		7
Other operating activities	'		'		'
Defined benefit plans - funding	-93		-59		-113
Other assets	8		-3		-28
Other liabilities	10		-31		-19
Net cash provided by (used in) operating activities	523		389		420
Cash Flows from Investing Activities	'		'		'
Expenditures for property, plant and equipment	-903		-624		-481
Expenditures for intangible assets	-39		-9		-9
Net (increase) decrease in notes receivable from affiliates	-150		'		'
Other investing activities	12		20		13
Net cash provided by (used in) investing activities	-1,080		-613		-477
Cash Flows from Financing Activities	'		'		'
Issuance of long-term debt	348		249		645
Retirement of long-term debt	'		'		-458
Contributions from parent	205		150		100
Redemption of preference stock of a subsidiary	'		-250		'
Payment of common stock dividends to parent	-127		-95		-92
Net increase (decrease) in short-term debt	20		'		'
Other financing activities	-4		-10		-22
Net cash provided by (used in) financing activities	442		44		173
Net Increase (Decrease) in Cash and Cash Equivalents	-115		-180		116
Cash and Cash Equivalents at Beginning of Period	140		320		204
Cash and Cash Equivalents at End of Period	25		140		320
Supplemental Disclosures of Cash Flow Information:	'		'		'
Interest - net of amount capitalized	87		81		75
Income taxes - net	-45		-42		-44
LG And E And KU Energy LLC [Member]	'		'		'
Cash Flows from Operating Activities	'		'		'
Net income (loss)	347		219		265
Adjustments to reconcile net income to net cash provided by (used in) operating activities	'		'		'
Depreciation	334		346		334
Amortization	22		27		27
Defined benefit plans - expense	48		40		51
Deferred income taxes and investment tax credits	254		133		218
Impairment of assets	'		25		'
Other	5		2		-9
Change in current assets and current liabilities	'		'		'
Accounts receivable	-91		-9		17
Accounts payable	40		1		-32
Accounts payable to affiliates	1		-1		'
Unbilled revenues	-24		-10		24
Fuel, materials and supplies	-1		8		15
Income tax receivable	1		2		37
Taxes payable	13		1		-2
Other	22		'		-1
Other operating activities	'		'		'
Defined benefit plans - funding	-168		-70		-170
Settlement of interest rate swaps	86		'		'
Other assets	'		-5		-11
Other liabilities	22		38		18
Net cash provided by (used in) operating activities	911		747		781
Cash Flows from Investing Activities	'		'		'
Expenditures for property, plant and equipment	-1,434		-768		-477
Proceeds from the sale of other investments	'		'		163
Net (increase) decrease in notes receivable from affiliates	-70		15		46
Net (increase) decrease in restricted cash and cash equivalents	9		-3		-9
Other investing activities	2		'		'
Net cash provided by (used in) investing activities	-1,493		-756		-277
Cash Flows from Financing Activities	'		'		'
Issuance of long-term debt	496		'		250
Retirement of long-term debt	'		'		-2
Contributions from member	243		'		'
Distributions to member	-254		-155		-533
Debt issuance and credit facility costs	-6		-2		-8
Net increase (decrease) in notes payable to affiliates	-25		25		'
Net increase (decrease) in short-term debt	120		125		-163
Net cash provided by (used in) financing activities	574		-7		-456
Net Increase (Decrease) in Cash and Cash Equivalents	-8		-16		48
Cash and Cash Equivalents at Beginning of Period	43		59		11
Cash and Cash Equivalents at End of Period	35		43		59
Supplemental Disclosures of Cash Flow Information:	'		'		'
Interest - net of amount capitalized	137		139		126
Income taxes - net	-67		-45		-98
Louisville Gas And Electric Co [Member]	'		'		'
Cash Flows from Operating Activities	'		'		'
Net income (loss)	163		123		124
Adjustments to reconcile net income to net cash provided by (used in) operating activities	'		'		'
Depreciation	148		152		147
Amortization	6		11		12
Defined benefit plans - expense	18		18		21
Deferred income taxes and investment tax credits	26		69		51
Other	9		-13		1
Change in current assets and current liabilities	'		'		'
Accounts receivable	-23		-2		25
Accounts payable	16		'		-24
Accounts payable to affiliates	1		-3		6
Unbilled revenues	-13		-7		16
Fuel, materials and supplies	-12		'		20
Taxes payable	9		-7		3
Other	8		-7		-7
Other operating activities	'		'		'
Defined benefit plans - funding	-48		-27		-70
Settlement of interest rate swaps	43		'		'
Other assets	-1		-21		-7
Other liabilities	6		22		7
Net cash provided by (used in) operating activities	356		308		325
Cash Flows from Investing Activities	'		'		'
Expenditures for property, plant and equipment	-577		-286		-196
Proceeds from the sale of other investments	'		'		163
Net (increase) decrease in restricted cash and cash equivalents	10		-3		-9
Net cash provided by (used in) investing activities	-567		-289		-42
Cash Flows from Financing Activities	'		'		'
Issuance of long-term debt	248		'		'
Contributions from parent	86		'		'
Payment of common stock dividends to parent	-99		-75		-83
Debt issuance and credit facility costs	-3		-2		-2
Net increase (decrease) in notes payable to affiliates	'		'		-12
Net increase (decrease) in short-term debt	-35		55		-163
Net cash provided by (used in) financing activities	197		-22		-260
Net Increase (Decrease) in Cash and Cash Equivalents	-14		-3		23
Cash and Cash Equivalents at Beginning of Period	22		25		2
Cash and Cash Equivalents at End of Period	8		22		25
Supplemental Disclosures of Cash Flow Information:	'		'		'
Interest - net of amount capitalized	36		39		40
Income taxes - net	51		5		20
Kentucky Utilities Co [Member]	'		'		'
Cash Flows from Operating Activities	'		'		'
Net income (loss)	228		137		178
Adjustments to reconcile net income to net cash provided by (used in) operating activities	'		'		'
Depreciation	186		193		186
Amortization	14		14		13
Defined benefit plans - expense	18		11		14
Deferred income taxes and investment tax credits	69		99		108
Impairment of assets	'		25		'
Other	-3		10		-10
Change in current assets and current liabilities	'		'		'
Accounts receivable	-37		-17		22
Accounts payable	23		1		2
Accounts payable to affiliates	-8		'		-12
Unbilled revenues	-11		-3		8
Fuel, materials and supplies	10		7		-5
Taxes payable	7		15		-14
Accrued interest	'		'		'
Other	10		6		-3
Other operating activities	'		'		'
Defined benefit plans - funding	-65		-21		-50
Settlement of interest rate swaps	43		'		'
Other assets	1		-3		-2
Other liabilities	10		26		9
Net cash provided by (used in) operating activities	495		500		444
Cash Flows from Investing Activities	'		'		'
Expenditures for property, plant and equipment	-855		-480		-279
Other investing activities	2		'		'
Net cash provided by (used in) investing activities	-853		-480		-279
Cash Flows from Financing Activities	'		'		'
Issuance of long-term debt	248		'		'
Contributions from parent	157		'		'
Payment of common stock dividends to parent	-124		-100		-124
Debt issuance and credit facility costs	-3		'		-3
Net increase (decrease) in notes payable to affiliates	'		'		-10
Net increase (decrease) in short-term debt	80		70		'
Net cash provided by (used in) financing activities	358		-30		-137
Net Increase (Decrease) in Cash and Cash Equivalents	'		-10		28
Cash and Cash Equivalents at Beginning of Period	21		31		3
Cash and Cash Equivalents at End of Period	21		21		31
Supplemental Disclosures of Cash Flow Information:	'		'		'
Interest - net of amount capitalized	61		62		60
Income taxes - net	$47		($39)		$16
[1]	Net income approximates comprehensive income.

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'		'
Cash and cash equivalents	$1,102		$901
Restricted cash and cash equivalents	83		54
Accounts receivable (less reserve:)	'		'
Customer	923		745
Other	97		79
Unbilled revenues	835		857
Fuel, materials and supplies	702		673
Prepayments	153		166
Deferred income taxes	246		30
Price risk management assets	942		1,525
Regulatory assets	33		19
Other current assets	37		19
Total Current Assets	5,153		5,068
Investments	'		'
Nuclear plant decommissioning trust funds	864		712
Other investments	43		47
Total Investments	907		759
Property, Plant and Equipment	'		'
Regulated utility plant	27,755		25,196
Less: accumulated depreciation - regulated utility plant	4,873		4,164
Regulated utility plant, net	22,882		21,032
Non-regulated property, plant and equipment	'		'
Generation	11,881		11,295
Nuclear fuel	591		524
Other	834		726
Less: accumulated depreciation - non-regulated property, plant and equipment	6,172		5,942
Non-regulated property, plant and equipment, net	7,134		6,603
Construction work in progress	3,071		2,397
Property, Plant and Equipment, net	33,087		30,032
Other Noncurrent Assets	'		'
Regulatory assets	1,246		1,483
Goodwill	4,225		4,158
Other intangibles	947		925
Price risk management assets	337		572
Other noncurrent assets	357		637
Total Other Noncurrent Assets	7,112		7,775
Total Assets	46,259		43,634
Current Liabilities	'		'
Short-term debt	701		652
Long-term debt due within one year	315		751
Accounts payable	1,308		1,252
Taxes	114		90
Interest	325		325
Dividends	232		210
Price risk management liabilities	829		1,065
Regulatory liabilities	90		61
Other current liabilities	998		1,219
Total Current Liabilities	4,912		5,625
Long-term Debt	20,592		18,725
Deferred Credits and Other Noncurrent Liabilities	'		'
Deferred income taxes	3,928		3,387
Investment tax credits	342		328
Price risk management liabilities	415		629
Accrued pension obligations	1,286		2,076
Asset retirement obligations	687		536
Regulatory liabilities	1,048		1,010
Other deferred credits and noncurrent liabilities	583		820
Total Deferred Credits and Other Noncurrent Liabilities	8,289		8,786
Commitments and Contingent Liabilities	'		'
Equity	'		'
Common stock	6	[1]	6	[1]
Additional paid-in capital	8,316		6,936
Earnings reinvested	5,709		5,478
Accumulated other comprehensive income (loss)	-1,565		-1,940
Total Stockholders' Equity	12,466		10,480
Noncontrolling Interests	'		18
Total Equity	12,466		10,498
Total Liabilities and Equity	46,259		43,634
PPL Energy Supply LLC [Member]	'		'
Current Assets	'		'
Cash and cash equivalents	239		413
Restricted cash and cash equivalents	68		46
Accounts receivable (less reserve:)	'		'
Customer	233		183
Other	97		31
Accounts receivable from affiliates	45		125
Unbilled revenues	286		369
Fuel, materials and supplies	358		327
Prepayments	20		15
Price risk management assets	860		1,511
Other current assets	27		10
Total Current Assets	2,233		3,030
Investments	'		'
Nuclear plant decommissioning trust funds	864		712
Other investments	37		41
Total Investments	901		753
Non-regulated property, plant and equipment	'		'
Generation	11,891		11,305
Nuclear fuel	591		524
Other	288		294
Less: accumulated depreciation - non-regulated property, plant and equipment	6,046		5,817
Non-regulated property, plant and equipment, net	6,724		6,306
Construction work in progress	450		987
Property, Plant and Equipment, net	7,174		7,293
Other Noncurrent Assets	'		'
Goodwill	86		86
Other intangibles	266		252
Price risk management assets	328		557
Other noncurrent assets	86		404
Total Other Noncurrent Assets	766		1,299
Total Assets	11,074		12,375
Current Liabilities	'		'
Short-term debt	'		356
Long-term debt due within one year	304		751
Accounts payable	393		438
Accounts payable to affiliates	4		31
Taxes	31		62
Interest	22		31
Price risk management liabilities	750		1,010
Deferred income taxes	9		158
Other current liabilities	269		319
Total Current Liabilities	1,782		3,156
Long-term Debt	2,221		2,521
Deferred Credits and Other Noncurrent Liabilities	'		'
Deferred income taxes	1,114		1,232
Investment tax credits	205		186
Price risk management liabilities	320		556
Accrued pension obligations	111		293
Asset retirement obligations	393		365
Other deferred credits and noncurrent liabilities	130		218
Total Deferred Credits and Other Noncurrent Liabilities	2,273		2,850
Commitments and Contingent Liabilities	'		'
Equity	'		'
Accumulated other comprehensive income (loss)	77		48
Member's Equity	4,798		3,830
Noncontrolling Interests	'		18
Total Equity	4,798		3,848
Total Liabilities and Equity	11,074		12,375
PPL Electric Utilities Corp [Member]	'		'
Current Assets	'		'
Cash and cash equivalents	25		140
Accounts receivable (less reserve:)	'		'
Customer	284		249
Other	5		5
Accounts receivable from affiliates	4		29
Unbilled revenues	116		110
Notes receivable from affiliates	150		'
Fuel, materials and supplies	35		39
Prepayments	40		76
Deferred income taxes	85		45
Regulatory assets	6		'
Other current assets	22		4
Total Current Assets	766		697
Property, Plant and Equipment	'		'
Regulated utility plant	6,886		6,286
Less: accumulated depreciation - regulated utility plant	2,417		2,316
Regulated utility plant, net	4,469		3,970
Non-regulated property, plant and equipment	'		'
Other, net	2		2
Construction work in progress	591		370
Property, Plant and Equipment, net	5,062		4,342
Other Noncurrent Assets	'		'
Regulatory assets	772		853
Other intangibles	211		171
Other noncurrent assets	35		55
Total Other Noncurrent Assets	1,018		1,079
Total Assets	6,846		6,118
Current Liabilities	'		'
Short-term debt	20		'
Long-term debt due within one year	10		'
Accounts payable	295		259
Accounts payable to affiliates	57		63
Taxes	51		12
Interest	34		26
Regulatory liabilities	76		52
Other current liabilities	82		93
Total Current Liabilities	625		505
Long-term Debt	2,305		1,967
Deferred Credits and Other Noncurrent Liabilities	'		'
Deferred income taxes	1,399		1,233
Investment tax credits	2		3
Accrued pension obligations	96		237
Regulatory liabilities	15		8
Other deferred credits and noncurrent liabilities	55		103
Total Deferred Credits and Other Noncurrent Liabilities	1,567		1,584
Commitments and Contingent Liabilities	'		'
Equity	'		'
Common stock	364	[2]	364	[2]
Additional paid-in capital	1,340		1,135
Earnings reinvested	645		563
Total Stockholders' Equity	2,349		2,062
Total Liabilities and Equity	6,846		6,118
LG And E And KU Energy LLC [Member]	'		'
Current Assets	'		'
Cash and cash equivalents	35		43
Accounts receivable (less reserve:)	'		'
Customer	224		133
Other	20		20
Accounts receivable from affiliates	'		1
Unbilled revenues	180		156
Notes receivable from affiliates	70		'
Fuel, materials and supplies	278		276
Prepayments	21		28
Price risk management assets from affiliates	'		14
Deferred income taxes	159		13
Regulatory assets	27		19
Other current assets	3		4
Total Current Assets	1,017		707
Property, Plant and Equipment	'		'
Regulated utility plant	8,526		8,073
Less: accumulated depreciation - regulated utility plant	778		519
Regulated utility plant, net	7,748		7,554
Non-regulated property, plant and equipment	'		'
Other, net	3		3
Construction work in progress	1,793		750
Property, Plant and Equipment, net	9,544		8,307
Other Noncurrent Assets	'		'
Regulatory assets	474		630
Goodwill	996		996
Other intangibles	221		271
Other noncurrent assets	98		108
Total Other Noncurrent Assets	1,789		2,005
Total Assets	12,350		11,019
Current Liabilities	'		'
Short-term debt	245		125
Notes payable with affiliates	'		25
Accounts payable	346		283
Accounts payable to affiliates	3		1
Taxes	39		26
Interest	23		21
Price risk management liabilities	4		5
Regulatory liabilities	14		9
Customer deposits	50		48
Other current liabilities	111		100
Total Current Liabilities	835		643
Long-term Debt	4,565		4,075
Deferred Credits and Other Noncurrent Liabilities	'		'
Deferred income taxes	965		541
Investment tax credits	135		138
Price risk management liabilities	32		53
Accrued pension obligations	152		414
Asset retirement obligations	245		125
Regulatory liabilities	1,033		1,002
Other deferred credits and noncurrent liabilities	238		242
Total Deferred Credits and Other Noncurrent Liabilities	2,800		2,515
Commitments and Contingent Liabilities	'		'
Equity	'		'
Accumulated other comprehensive income (loss)	13		-15
Member's Equity	4,150		3,786
Total Liabilities and Equity	12,350		11,019
Louisville Gas And Electric Co [Member]	'		'
Current Assets	'		'
Cash and cash equivalents	8		22
Accounts receivable (less reserve:)	'		'
Customer	102		59
Other	9		16
Accounts receivable from affiliates	'		14
Unbilled revenues	85		72
Fuel, materials and supplies	154		142
Prepayments	7		7
Price risk management assets from affiliates	'		7
Regulatory assets	17		19
Other current assets	3		1
Total Current Assets	385		359
Property, Plant and Equipment	'		'
Regulated utility plant	3,383		3,187
Less: accumulated depreciation - regulated utility plant	332		220
Regulated utility plant, net	3,051		2,967
Non-regulated property, plant and equipment	'		'
Construction work in progress	651		259
Property, Plant and Equipment, net	3,702		3,226
Other Noncurrent Assets	'		'
Regulatory assets	303		400
Goodwill	389		389
Other intangibles	120		144
Other noncurrent assets	35		44
Total Other Noncurrent Assets	847		977
Total Assets	4,934		4,562
Current Liabilities	'		'
Short-term debt	20		55
Accounts payable	166		117
Accounts payable to affiliates	24		23
Taxes	11		2
Interest	6		5
Price risk management liabilities	4		5
Regulatory liabilities	9		4
Customer deposits	24		23
Other current liabilities	32		34
Total Current Liabilities	296		268
Long-term Debt	1,353		1,112
Deferred Credits and Other Noncurrent Liabilities	'		'
Deferred income taxes	582		544
Investment tax credits	38		40
Price risk management liabilities	32		53
Accrued pension obligations	19		102
Asset retirement obligations	68		56
Regulatory liabilities	482		471
Other deferred credits and noncurrent liabilities	104		106
Total Deferred Credits and Other Noncurrent Liabilities	1,325		1,372
Commitments and Contingent Liabilities	'		'
Equity	'		'
Common stock	424	[3]	424	[3]
Additional paid-in capital	1,364		1,278
Earnings reinvested	172		108
Total Stockholders' Equity	1,960		1,810
Total Liabilities and Equity	4,934		4,562
Kentucky Utilities Co [Member]	'		'
Current Assets	'		'
Cash and cash equivalents	21		21
Accounts receivable (less reserve:)	'		'
Customer	122		74
Other	9		13
Accounts receivable from affiliates	'		7
Unbilled revenues	95		84
Fuel, materials and supplies	124		134
Prepayments	4		10
Price risk management assets from affiliates	'		7
Regulatory assets	10		'
Other current assets	6		6
Total Current Assets	391		356
Property, Plant and Equipment	'		'
Regulated utility plant	5,143		4,886
Less: accumulated depreciation - regulated utility plant	446		299
Regulated utility plant, net	4,697		4,587
Non-regulated property, plant and equipment	'		'
Other, net	1		1
Construction work in progress	1,139		490
Property, Plant and Equipment, net	5,837		5,078
Other Noncurrent Assets	'		'
Regulatory assets	171		230
Goodwill	607		607
Other intangibles	101		127
Other noncurrent assets	56		57
Total Other Noncurrent Assets	935		1,021
Total Assets	7,163		6,455
Current Liabilities	'		'
Short-term debt	150		70
Accounts payable	159		147
Accounts payable to affiliates	25		33
Taxes	33		26
Interest	11		10
Regulatory liabilities	5		5
Customer deposits	26		25
Other current liabilities	36		33
Total Current Liabilities	445		349
Long-term Debt	2,091		1,842
Deferred Credits and Other Noncurrent Liabilities	'		'
Deferred income taxes	658		587
Investment tax credits	97		98
Accrued pension obligations	11		104
Asset retirement obligations	177		69
Regulatory liabilities	551		531
Other deferred credits and noncurrent liabilities	89		92
Total Deferred Credits and Other Noncurrent Liabilities	1,583		1,481
Commitments and Contingent Liabilities	'		'
Equity	'		'
Common stock	308	[4]	308	[4]
Additional paid-in capital	2,505		2,348
Earnings reinvested	230		126
Accumulated other comprehensive income (loss)	1		1
Total Stockholders' Equity	3,044		2,783
Total Liabilities and Equity	$7,163		$6,455
[1]	780,000 shares authorized; 630,321 and 581,944 shares issued and outstanding at December 31, 2013 and 2012.
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2013 and 2012.
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2013 and December 31, 2012.
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2013 and December 31, 2012.

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data in Thousands, unless otherwise specified
Receivables Net Current [Abstract]	'	'
Accounts receivable reserve for uncollectible accounts	$64	$64
Property, Plant and Equipment	'	'
PP&E, net from the consolidation of a VIE	'	428
Equity	'	'
Common stock par value	$0.01	$0.01
Common stock shares authorized	780,000	780,000
Common stock shares issued	630,321	581,944
Common stock shares outstanding	630,321	581,944
PPL Energy Supply LLC [Member]	'	'
Receivables Net Current [Abstract]	'	'
Accounts receivable reserve for uncollectible accounts	21	23
Property, Plant and Equipment	'	'
PP&E, net from the consolidation of a VIE	'	428
PPL Electric Utilities Corp [Member]	'	'
Receivables Net Current [Abstract]	'	'
Accounts receivable reserve for uncollectible accounts	18	18
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	22	19
Louisville Gas And Electric Co [Member]	'	'
Receivables Net Current [Abstract]	'	'
Accounts receivable reserve for uncollectible accounts	2	1
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	$4	$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_EQU

CONSOLIDATED STATEMENTS OF EQUITY (USD $)

Total

Common Stock

Additional Paid-in Capital

Earnings Reinvested

Accumulated Other Comprehensive Loss

Member's Equity

Non-controlling Interests

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

In Millions, except Share data in Thousands

Member's Equity

Non-controlling Interests

Common Stock

Preferred Securities

Additional Paid-in Capital

Earnings Reinvested

Member's Equity

Common Stock

Additional Paid-in Capital

Earnings Reinvested

Common Stock

Additional Paid-in Capital

Earnings Reinvested

Accumulated Other Comprehensive Loss

Balance at beginning of period at Dec. 31, 2010

'

'

'

'

'

'

'

'

'

'

$1,944

$364

$250

$879

$451

'

'

$1,721

$424

$1,278

$19

$2,691

$308

$2,348

$35

'

Balance at beginning of period at Dec. 31, 2010

8,478

5

4,602

4,082

-479

[1]

'

268

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period - shares at Dec. 31, 2010

'

483,391

[1],[2]

'

'

'

'

'

'

'

'

'

66,368

[3]

'

'

'

'

'

'

21,294

[4]

'

'

'

37,818

[5]

'

'

'

Balance at beginning of period at Dec. 31, 2010

[1]

'

'

'

'

'

'

'

4,509

4,491

18

'

'

'

'

'

'

4,011

'

'

'

'

'

'

'

'

'

Common stock shares issued

[2],[6]

'

95,014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued

2,345

1

[6]

2,344

[6]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase Contracts

[7]

-143

'

-143

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock-based compensation

[8]

10

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

1,512

'

'

1,495

'

'

17

769

768

1

189

[9]

'

'

'

189

265

'

124

'

'

124

178

'

'

178

'

Dividends, dividend equivalents, redemptions and distributions

[10]

-797

'

'

-780

'

'

-17

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash dividends declared on preferred securities

'

'

'

'

'

'

'

'

'

'

-16

'

'

'

-16

'

'

'

'

'

'

'

'

'

'

'

Cash dividends declared on common stock

'

'

'

'

'

'

'

'

'

'

-92

'

'

'

-92

'

'

-83

'

'

-83

'

'

'

-124

'

Distributions to member

'

'

'

'

'

'

'

-317

-316

-1

'

'

'

'

'

'

-533

'

'

'

'

'

'

'

'

'

Distribution of membership interest in PPL Global

[11]

'

'

'

'

'

-1,288

'

-1,288

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions from member

'

'

'

'

'

'

'

461

461

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital contributions from parent

'

'

'

'

'

'

'

'

'

'

100

'

'

100

'

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income (loss)

-309

'

'

'

-309

'

'

-97

-97

'

'

'

'

'

'

-2

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2011

'

'

'

'

'

'

'

'

'

'

2,125

364

'

979

532

'

'

1,762

424

1,278

60

2,745

308

2,348

89

'

Balance at end of period at Dec. 31, 2011

11,096

6

6,813

4,797

-788

[1]

'

268

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2011

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,741

'

'

'

'

'

'

'

'

'

Balance at end of period - shares at Dec. 31, 2011

'

578,405

[1],[2]

'

'

'

'

'

'

'

'

'

66,368

[3]

'

'

'

'

'

'

21,294

[4]

'

'

'

37,818

[5]

'

'

'

Balance at end of period at Dec. 31, 2011

[1]

'

'

'

'

'

'

'

4,037

4,019

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

545

[12]

'

'

'

'

'

'

'

'

'

37

[13]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Mar. 31, 2012

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period at Dec. 31, 2011

'

'

'

'

'

'

'

'

'

'

2,125

364

250

979

532

'

'

1,762

424

1,278

60

2,745

308

2,348

89

'

Balance at beginning of period at Dec. 31, 2011

11,096

6

6,813

4,797

-788

[1]

'

268

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period at Dec. 31, 2011

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,741

'

'

'

'

'

'

'

'

'

Balance at beginning of period - shares at Dec. 31, 2011

'

578,405

[1],[2]

'

'

'

'

'

'

'

'

'

66,368

[3]

'

'

'

'

'

'

21,294

[4]

'

'

'

37,818

[5]

'

'

'

Balance at beginning of period at Dec. 31, 2011

[1]

'

'

'

'

'

'

'

4,037

4,019

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock shares issued

[2],[6]

'

3,543

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued

99

'

99

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock shares repurchased

[2]

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock-based compensation

[8]

18

'

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

1,531

'

'

1,526

'

'

5

475

474

1

[1]

136

[9]

'

'

'

136

219

'

123

'

'

123

137

'

'

137

'

Dividends, dividend equivalents, redemptions and distributions

[10]

-1,094

'

6

-845

'

'

-255

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash dividends declared on preferred securities

'

'

'

'

'

'

'

'

'

'

-4

'

'

'

-4

'

'

'

'

'

'

'

'

'

'

'

Cash dividends declared on common stock

'

'

'

'

'

'

'

'

'

'

-95

'

'

'

-95

'

'

-75

'

'

-75

-100

'

'

-100

'

Distributions to member

'

'

'

'

'

'

'

-788

-787

-1

'

'

'

'

'

'

-155

'

'

'

'

'

'

'

'

'

Contributions from member

'

'

'

'

'

'

'

563

563

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital contributions from parent

'

'

'

'

'

'

'

'

'

'

150

'

'

150

'

'

'

'

'

'

'

'

'

'

'

'

Redemption of preferred securities

[14]

'

'

'

'

'

'

'

'

'

'

-250

'

-250

6

-6

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income (loss)

-1,152

'

'

'

-1,152

'

'

-439

-439

'

'

'

'

'

'

-19

'

'

'

'

'

1

'

'

'

1

Balance at end of period at Dec. 31, 2012

10,480

'

'

'

'

'

'

'

'

'

2,062

364

'

1,135

563

'

'

1,810

424

1,278

108

2,783

308

2,348

126

1

[1]

Balance at end of period at Dec. 31, 2012

10,498

6

6,936

5,478

-1,940

[1]

'

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2012

'

'

'

'

'

'

'

3,830

'

'

'

'

'

'

'

3,786

'

'

'

'

'

'

'

'

'

'

Balance at end of period - shares at Dec. 31, 2012

581,944

581,944

[1],[2]

'

'

'

'

'

'

'

'

66,368

66,368

[3]

'

'

'

'

'

21,294

21,294

[4]

'

'

37,818

37,818

[5]

'

'

'

Balance at end of period at Dec. 31, 2012

'

'

'

'

'

'

'

3,848

3,830

[1]

18

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period at Sep. 30, 2012

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

360

[12]

'

'

'

'

'

'

'

'

'

37

[13]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2012

10,480

'

'

'

'

'

'

'

'

'

2,062

364

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2012

10,498

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period - shares at Dec. 31, 2012

581,944

'

'

'

'

'

'

'

'

'

66,368

66,368

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

413

[12]

'

'

'

'

'

'

'

'

'

64

[13]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Mar. 31, 2013

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period at Dec. 31, 2012

10,480

'

'

'

'

'

'

'

'

'

2,062

364

'

1,135

563

'

'

1,810

424

1,278

108

2,783

308

2,348

126

1

[1]

Balance at beginning of period at Dec. 31, 2012

10,498

6

6,936

5,478

-1,940

[1]

'

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period at Dec. 31, 2012

'

'

'

'

'

'

'

3,830

'

'

'

'

'

'

'

3,786

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period - shares at Dec. 31, 2012

581,944

581,944

[1],[2]

'

'

'

'

'

'

'

'

66,368

66,368

[3]

'

'

'

'

'

21,294

21,294

[4]

'

'

37,818

37,818

[5]

'

'

'

Balance at beginning of period at Dec. 31, 2012

'

'

'

'

'

'

'

3,848

3,830

[1]

18

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock shares issued

[2],[6]

'

50,807

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued

1,437

'

1,437

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock shares repurchased

2,400

-2,430

[15],[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock repurchased

[15]

-74

'

-74

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash settlement of equity forward agreements

[15]

-13

'

-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock-based compensation

[8]

30

'

30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

1,131

'

'

1,130

'

'

1

-229

-230

1

209

[9]

'

'

'

209

347

'

163

'

'

163

228

'

'

228

'

Dividends, dividend equivalents, redemptions and distributions

[10]

-918

'

'

-899

'

'

-19

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash dividends declared on common stock

'

'

'

'

'

'

'

'

'

'

-127

'

'

'

-127

'

'

-99

'

'

-99

-124

'

'

-124

'

Distributions to member

'

'

'

'

'

'

'

-427

[16]

-408

[16]

-19

[16]

'

'

'

'

'

'

-254

'

'

'

'

'

'

'

'

'

Contributions from member

'

'

'

'

'

'

'

1,577

1,577

'

'

'

'

'

'

'

243

'

'

'

'

'

'

'

'

'

Capital contributions from parent

'

'

'

'

'

'

'

'

'

'

205

'

'

205

'

'

'

86

'

86

'

157

'

157

'

'

Other comprehensive income (loss)

375

'

'

'

375

'

'

29

29

'

'

'

'

'

'

28

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2013

12,466

'

'

'

'

'

'

'

'

'

2,349

364

'

1,340

645

'

'

1,960

424

1,364

172

3,044

308

2,505

230

1

[1]

Balance at end of period at Dec. 31, 2013

12,466

6

8,316

5,709

-1,565

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2013

'

'

'

'

'

'

'

4,798

'

'

'

'

'

'

'

4,150

'

'

'

'

'

'

'

'

'

'

Balance at end of period - shares at Dec. 31, 2013

630,321

630,321

[1],[2]

'

'

'

'

'

'

'

'

66,368

66,368

[3]

'

'

'

'

'

21,294

21,294

[4]

'

'

37,818

37,818

[5]

'

'

'

Balance at end of period at Dec. 31, 2013

'

'

'

'

'

'

'

4,798

4,798

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period at Sep. 30, 2013

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

-98

[12],[17]

'

'

'

'

'

'

'

'

'

49

[13]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2013

12,466

'

'

'

'

'

'

'

'

'

2,349

364

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period at Dec. 31, 2013

$12,466

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period - shares at Dec. 31, 2013

630,321

'

'

'

'

'

'

'

'

'

66,368

66,368

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

See Note 24 for disclosure of balances of each component of AOCI.

[2]

Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.

[3]

Shares in thousands. All common shares of PPL Electric stock are owned by PPL.

[4]

Shares in thousands. All common shares of LG&E stock are owned by LKE.

[5]

Shares in thousands. All common shares of KU stock are owned by LKE.

[6]

All years presented include shares of common stock issued through various stock and incentive compensation plans. 2011 includes the April issuance of common stock and 2013 includes the April and July issuances of common stock. See Note 7 for additional information.

[7]

Represents $123 million for the 2011 Purchase Contracts and $20 million of related fees and expenses, net of tax. See Note 7 for additional information.

[8]

2013, 2012 and 2011 include $50 million, $47 million and $33 million of stock-based compensation expense related to new and existing unvested equity awards, and $(20) million, $(29) million and $(23) million related primarily to the reclassification from "Stock-based compensation" to "Common stock issued" for the issuance of common stock after applicable equity award vesting periods and tax adjustments related to stock-based compensation.

[9]

Net income approximates comprehensive income.

[10]

"Earnings reinvested" includes dividends and dividend equivalents on PPL common stock and restricted stock units. "Noncontrolling interests" includes dividends, redemptions and distributions to noncontrolling interests. In December 2013, a distribution to noncontrolling interests was made related to the purchase of the Lower Mt. Bethel plant. See Note 22 for additional information. In June 2012, PPL Electric redeemed all of its outstanding preference stock at par value, which was classified as noncontrolling interest. See Note 3 for additional information.

[11]

See Note 9 for additional information.

[12]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[13]

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.

[14]

In June 2012, PPL Electric redeemed all of its outstanding preference stock. See Note 3 for additional information.

[15]

See Note 7 for additional information.

[16]

In December 2013, a distribution to noncontrolling interests was made related to the purchase of the Lower Mt. Bethel plant. See Note 22 for additional information.

[17]

Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements for additional information.

CONSOLIDATED_STATEMENTS_OF_EQU1

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Vote per share of PPL's common stock	1	1	1
Present value of the purchase Contract component of the Equity Units	'	'	$123
Issuance costs related to the Equity Units allocated to capital in excess of par, net of tax	'	'	20
Stock-based compensation expense related to new and existing unvested equity awards	50	47	33
Reclassification From Share Based Compensation To Common Stock Issued	($20)	($29)	($23)

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
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 the applicable disclosure or within the applicable disclosure for its related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant.
	Business and Consolidation
	(PPL)
	PPL is an energy and utility holding company that, through its subsidiaries, is primarily engaged in: 1) the regulated distribution of electricity in the U.K.; 2) the regulated generation, transmission, distribution and sale of electricity and the regulated distribution and sale of natural gas, primarily in Kentucky; 3) the regulated transmission, distribution and sale of electricity in Pennsylvania; and 4) the competitive generation and marketing of electricity in portions of the northeastern and northwestern U.S. Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global, LKE (including its principal subsidiaries, LG&E and KU), PPL Electric and PPL Energy Supply (including its principal subsidiaries, PPL EnergyPlus and PPL Generation). PPL's corporate level financing subsidiary is PPL Capital Funding.
	WPD, a subsidiary of PPL Global, through indirect wholly owned subsidiaries operates regulated distribution networks providing electricity service in the U.K. WPD serves end-users in Wales and southwest and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands) and WPD (West Midlands).
	On April 1, 2011, PPL, through its indirect, wholly owned subsidiary PPL WEM, completed its acquisition of all of the outstanding ordinary share capital of Central Networks East plc and Central Networks Limited, the sole owner of Central Networks West plc, together with certain other related assets and liabilities (collectively referred to as Central Networks and subsequently referred to as WPD Midlands), from subsidiaries of E.ON AG. WPD Midlands' operating results are included in PPL's results of operations for the full year of 2013 and 2012, but as PPL is consolidating WPD Midlands on a one-month lag, eight months of operating results are included in PPL's results of operations for 2011.
	See Note 10 for additional information regarding the acquisition of WPD Midlands.
	PPL consolidates WPD, including WPD Midlands, on a one-month lag. Material intervening 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 Energy Supply)
	PPL Energy Supply is an energy company conducting business primarily through its principal subsidiaries PPL Generation and PPL EnergyPlus. PPL Generation owns and operates a portfolio of competitive domestic power generating assets. These power plants are located in Pennsylvania and Montana and use well-diversified fuel sources including coal, uranium, natural gas, oil and water. PPL EnergyPlus sells electricity produced by PPL Generation subsidiaries, participates in wholesale market load-following auctions, and markets various energy products and commodities such as: capacity, transmission, FTRs, coal, natural gas, oil, uranium, emission allowances, RECs and other commodities in competitive wholesale and competitive retail markets, primarily in the northeastern and northwestern U.S.
	On April 13, 2012, an indirect, wholly owned subsidiary of PPL Energy Supply completed the Ironwood Acquisition. See Note 10 for additional information.
	(PPL and PPL Electric)
	PPL Electric is a cost-based rate-regulated utility subsidiary of PPL. PPL Electric's principal business is the regulated transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR.
	(PPL, LKE, LG&E and KU)
	LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, LG&E and KU. LG&E and KU are engaged in the regulated generation, transmission, distribution and sale of electricity. LG&E also engages in the regulated 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, PPL Energy Supply and LKE)
	"Income (Loss) from Discontinued Operations (net of income taxes)" on the Statements of Income includes the activities of various businesses that were sold or distributed. See Note 9 for additional information. The Statements of Cash Flows do not separately report the cash flows of the Discontinued Operations.
	(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 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. For PPL and PPL Energy Supply, see Note 22 for information regarding a previously consolidated VIE. Investments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. All significant intercompany transactions have been eliminated. Any noncontrolling interests are reflected in the financial statements.
	The financial statements of PPL, PPL Energy Supply, 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 14 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 except PPL Energy Supply)
	PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Rates are generally established based on a historical or future test period adjusted to exclude unusual or nonrecurring items. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
	Accounting Records (All Registrants except PPL Energy Supply)
	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 events. Loss accruals for environmental remediation are discounted when appropriate.
	The accrual of contingencies that might result in gains is not recorded, unless realization is assured.
	Changes in Classification
	The classification of certain amounts in the 2012 and 2011 financial statements have been changed to conform to the current presentation. The changes in classification 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 except PPL Electric)
	Energy and energy-related contracts are used to hedge the variability of expected cash flows associated with the generating units and marketing activities, as well as for trading purposes at PPL Energy Supply. Interest rate contracts are used to hedge exposures to changes in the fair value of debt instruments and to hedge exposures to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Foreign currency exchange contracts are used to hedge foreign currency exposures, primarily associated with PPL's investments in U.K. subsidiaries. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation.
	Certain energy and energy-related contracts meet the definition of a derivative, while others do 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 energy contracts have been excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. All other contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. These contracts are recorded as "Price risk management assets" and "Price risk management liabilities" on the Balance Sheets. 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." PPL considers intra-month transactions to be spot activity, which is not accounted for as a derivative.
	Energy and energy-related contracts are assigned a strategy and accounting classification. Processes exist that allow for subsequent review and validation of the contract information. See Note 19 for more information. The accounting department provides the traders and the risk management department with guidelines on appropriate accounting classifications for various contract types and strategies. Some examples of these guidelines include, but are not limited to:
	       Physical coal, limestone, lime, uranium, electric transmission, gas transportation, gas storage and renewable energy credit contracts not traded on an exchange are not derivatives due to the lack of net settlement provisions.
	       Only contracts where physical delivery is deemed probable throughout the entire term of the contract can qualify for NPNS.
	       Physical transactions that permit cash settlement and financial transactions do not qualify for NPNS because physical delivery cannot be asserted; however, these transactions can receive cash flow hedge treatment if they effectively hedge the volatility in the future cash flows for energy-related commodities.
	       Certain purchased option contracts or net purchased option collars may receive cash flow hedge treatment.
	       Derivative transactions that do not qualify for NPNS or cash flow hedge treatment, or for which NPNS or cash flow hedge treatment is not elected, are recorded at fair value through earnings.
	A similar process is also followed by the treasury department as it relates to interest rate and foreign currency derivatives. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to:
	       Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring.
	       Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges.
	       Transactions entered into to hedge fluctuations in the fair value of existing debt can be designated 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 treatment are marked to fair value through earnings. These transactions generally include foreign currency swaps 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 included in customer rates.
	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 Energy Supply reflects its net realized and unrealized gains and losses associated with all derivatives that are held for trading purposes in "Unregulated wholesale energy" on the Statements of Income.
	See Notes 18 and 19 for additional information on derivatives.
	(PPL and PPL Electric)
	To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. See Notes 18 and 19 for additional information.
Revenue
Utility Revenue (PPL)
For the years ended December 31, the Statements of Income "Utility" line item contains rate-regulated revenue from the following:
				2013			2012			2011
Domestic electric and gas revenue (a)			$	4,842		$	4,519		$	4,674
U.K. electric revenue (b)				2,359			2,289			1,618
	Total		$	7,201		$	6,808		$	6,292
(a)       Represents revenue from regulated generation, transmission and/or distribution in Pennsylvania, Kentucky, Virginia and Tennessee, including regulated wholesale revenue.
(b)       Represents electric distribution revenue from the operation of WPD's distribution networks. 2011 includes eight months of revenue for WPD Midlands.
Revenue Recognition
(All Registrants)
Operating revenues, except for certain energy and energy-related contracts that meet the definition of derivative instruments and "Energy-related businesses," are 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 being read at the end of the month. Unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh by the estimated average cents per kWh. Unbilled wholesale energy revenues are recorded at month-end to reflect estimated amounts until actual dollars and MWhs are confirmed and invoiced. Any difference between estimated and actual revenues is adjusted the following month.
Certain PPL subsidiaries participate primarily in the PJM RTO, as well as in other RTOs and ISOs. In PJM, PPL EnergyPlus is a marketer, a load-serving entity and a seller for PPL Energy Supply's generation subsidiaries. A function of interchange accounting is to match participants' MWh entitlements (generation plus scheduled bilateral purchases) against their MWh obligations (load plus scheduled bilateral sales) during every hour of every day. If the net result during any given hour is an entitlement, the participant is credited with a spot-market sale to the RTO at the respective market price for that hour; if the net result is an obligation, the participant is charged with a spot-market purchase at the respective market price for that hour. PPL Energy Supply records the hourly net sales in its Statements of Income as "Unregulated wholesale energy" if in a net sales position and "Energy purchases" if in a net purchase position.
(PPL)
WPD's revenue is primarily from charges to suppliers to use its distribution system to deliver electricity to the end-user. WPD's allowed revenue is not dependent on volume delivered over each price control period. 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 given period. Under recoveries are recovered and recorded in the next regulatory year. Over-recoveries are reflected in the current period as a liability and are not included in revenue.
(PPL and PPL Energy Supply)
PPL Energy Supply records non-derivative energy marketing activity in the period when the energy is delivered. Generally, sales contracts held for non-trading purposes are reported gross on the Statements of Income within "Unregulated wholesale energy" and "Unregulated retail energy." However, non-trading physical sales and purchases of electricity at major market delivery points (which is any delivery point with liquid pricing available, such as the pricing hub for PJM West), are netted and reported in the Statements of Income within "Unregulated wholesale energy" or "Energy purchases," depending on the net hourly position. Certain energy and energy-related contracts that meet the definition of derivative instruments are recorded at fair value with subsequent changes in fair value recognized as revenue or expense (see Note 19), unless hedge accounting is applied or NPNS is elected. If derivatives meet cash flow hedging criteria, changes in fair value are recorded in AOCI. The unrealized and realized results of derivative and non-derivative contracts that are designated as proprietary trading activities are reported net on the Statements of Income within "Unregulated wholesale energy."
"Energy-related businesses" revenue primarily includes revenue from PPL Energy Supply's mechanical contracting and engineering subsidiaries. These subsidiaries record revenue from construction contracts on the percentage-of-completion method of accounting, measured by the actual cost incurred to date as a percentage of the estimated total cost for each contract. Accordingly, costs and estimated earnings in excess of billings on uncompleted contracts are recorded within "Unbilled revenues" on the Balance Sheets, and billings in excess of costs and estimated earnings on uncompleted contracts are recorded within "Other current liabilities" on the Balance Sheets. The amount of costs and estimated earnings in excess of billings was $14 million and $12 million at December 31, 2013 and 2012, and the amount of billings in excess of costs and estimated earnings was $75 million and $70 million at December 31, 2013 and 2012.
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. See Note 10 for information related to the acquisition of WPD Midlands.
(PPL, PPL Energy Supply and PPL Electric)
In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative suppliers (including PPL EnergyPlus) at a discount, which reflects a provision for uncollectible accounts. The alternative 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 the purchase price paid and are classified as Level 2 in the fair value hierarchy. During 2013, 2012 and 2011, PPL Electric purchased $985 million, $848 million and $875 million of accounts receivable from unaffiliated third parties. During 2013, 2012 and 2011, PPL Electric purchased $294 million, $313 million and $264 million of accounts receivable from PPL EnergyPlus.
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 the 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
2013		$	64			$	39			$	4	(d)		$	43			$	64
2012			54				55	(b)							45				64
2011			55				65	(b)							66	(c)			54
PPL Energy Supply
2013		$	23			$	1							$	3			$	21
2012			15				12	(b)							4				23
2011			20				14	(b)							19	(c)			15
PPL Electric
2013		$	18			$	32							$	32			$	18
2012			17				32								31				18
2011			17				33								33				17
LKE
2013		$	19			$	4			$	4	(d)		$	5			$	22
2012			17				9								7				19
2011			17				15								15				17
LG&E
2013		$	1			$	2			$	1	(d)		$	2			$	2
2012			2				2								3				1
2011			2				5								5				2
KU
2013		$	2			$	3			$	3	(d)		$	4			$	4
2012			2				4								4				2
2011			6				6								10				2
(a)       Primarily related to uncollectible accounts written off.
(b)       Includes amounts related to the SMGT bankruptcy. See Note 15 for additional information.
(c)       Includes amounts related to the June 2011, FERC approved settlement agreement between PPL and the California ISO related to the sales made to the California ISO during the period October 2000 through June 2001 that were not paid to PPL subsidiaries. Therefore, the receivable and the related allowance for doubtful accounts were reversed and the settlement recorded.
(d)       Primarily related to capital projects, thus the provision was recorded as an adjustment to construction work in progress.
Cash
(All Registrants)
Cash Equivalents
All highly liquid investments with original maturities of three months or less are considered to be cash equivalents.
Restricted Cash and Cash Equivalents
Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. 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 shown as "Restricted cash and cash equivalents" for PPL and PPL Energy Supply and included in "Other current assets" for PPL Electric, LKE, LG&E and KU while the noncurrent portion is included in "Other noncurrent assets" for all Registrants.
(All Registrants except KU)
At December 31, the balances of restricted cash and cash equivalents included the following.
					PPL						PPL Energy Supply						PPL Electric					LKE				LG&E
					2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
Margin deposits posted to
	counterparties				$	67		$	43		$	67		$	43
Cash collateral posted to
	counterparties					22			32													$	22	$	32	$	22	$	32
Low carbon network fund (a)						27			14
Funds deposited with a trustee (b)						12			13								$	12		$	13
Ironwood debt service reserves						17			17			17			17
Other						11			16			1			3
		Total			$	156		$	135		$	85		$	63		$	12		$	13	$	22	$	32	$	22	$	32
(a)       Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
(b)       Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
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 securities including investments in the NDT funds and defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk.
The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows:
       Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.
       Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability.
       Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value.
Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy.
Investments
(All Registrants)
Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term.
Short-term Investments
Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets.
Investments in Debt and Equity Securities
Investments in debt securities are classified as held-to-maturity and measured at amortized cost when there is an intent and ability to hold the securities to maturity. Debt and equity securities held principally to capitalize on fluctuations in their value with the intention of selling them in the near-term are classified as trading. All other investments in debt and equity securities are classified as available-for-sale. Both trading and available-for-sale securities are carried at fair value. The specific identification method is used to calculate realized gains and losses on debt and equity securities. Any unrealized gains and losses on trading securities are included in earnings.
The criteria for determining whether a decline in fair value of a debt security is other than temporary and whether the other-than-temporary impairment is recognized in earnings or reported in OCI require that when a debt security is in an unrealized loss position and:
       there is an intent or a requirement to sell the security before recovery, the other-than-temporary impairment is recognized currently in earnings; or
       there is no intent or requirement to sell the security before recovery, the portion of the other-than-temporary impairment that is considered a credit loss, if any, is recognized currently in earnings and the remainder of the other-than-temporary impairment is reported in OCI, net of tax.
Unrealized gains and losses on available-for-sale equity securities are reported, net of tax, in OCI. When an equity security's decline in fair value below amortized cost is determined to be an other-than-temporary impairment, the unrealized loss is recognized currently in earnings. See Notes 18 and 23 for additional information on investments in debt and equity securities.
Equity Method Investment (PPL, LKE and KU)
Investments in entities over which PPL, LKE and KU have the ability to exercise significant influence, but not control, are accounted for using the equity method of accounting and are reported in “Other Investments” on PPL's Balance Sheet and in “Other noncurrent assets” on LKE's and KU's Balance Sheets. In accordance with the accounting guidance for equity method investments, the recoverability of the investment is periodically assessed. If an identified event or change in circumstances requires an impairment evaluation, the fair value of the investment is assessed. The difference between the carrying amount of the investment and its estimated fair value is recognized as an impairment loss when the loss in value is deemed other-than-temporary and such loss is included in “Other-Than-Temporary Impairments” on the Statements of Income.
KU owns 20% of the common stock of EEI, which is accounted for as an equity method investment. During 2012, KU recorded losses of $8 million from its share of EEI's operating results. In December 2012, KU concluded that an other-than-temporary decline in the value of its investment in EEI had occurred. KU recorded an impairment charge of $25 million ($15 million, after-tax) which reduced the investment balance to zero, the estimated fair value at December 31, 2013 and 2012. See Note 18 for additional information.
Cost Method Investment (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 LKE, LG&E and KU Balance Sheets and in “Other investments” on the PPL Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU.
LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU may be 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 regulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 15 and 20 for additional discussion on 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, such as the Ironwood and WPD Midlands acquisitions, 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 costs 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 cost 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.
(All Registrants except PPL Energy Supply)
AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC as a return is provided on construction work in progress.
(PPL and PPL Energy Supply)
Nuclear fuel-related costs, including fuel, conversion, enrichment, fabrication and assemblies, are capitalized as PP&E. Such costs are amortized as the fuel is spent using the units-of-production method and included in "Fuel" on the Statements of Income.
PPL Energy Supply capitalizes interest costs as part of construction costs. Capitalized interest, excluding AFUDC for PPL, is as follows.
					PPL
		PPL			Energy Supply
2013		$	46		$	37
2012			53			47
2011			51			47
Depreciation
(All Registrants)
Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators.
Following are the weighted-average rates of depreciation at December 31.
		2013
					PPL
					Energy			PPL
		PPL			Supply			Electric			LKE				LG&E			KU
Regulated utility plant			2.94						2.61				4.07			4.52			3.77
Non-regulated PP&E - Generation			3.1			3.1
		2012
					PPL
					Energy			PPL
		PPL			Supply			Electric			LKE				LG&E			KU
Regulated utility plant			3.12						2.57				4.39			4.91			4.06
Non-regulated PP&E - Generation			3.05			3.05
(PPL, LKE, LG&E and KU)
The KPSC approved new lower depreciation rates for LG&E and KU as part of the rate-case settlement agreement reached in November 2012. The new rates became effective January 1, 2013 and resulted in lower depreciation of approximately $22 million ($8 million for LG&E and $14 million for KU) in 2013, exclusive of net additions to PP&E.
(All Registrants)
Goodwill and Other Intangible Assets
Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination.
Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets.
When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider the expected use of the asset; the expected useful life of other assets to which the useful life of the intangible asset may relate; legal, regulatory, or contractual provisions that may limit the useful life; the company's historical experience as evidence of its ability to support renewal or extension; the effects of obsolescence, demand, competition, and other economic factors; and the level of maintenance expenditures required to obtain the expected future cash flows from the asset.
PPL and PPL Energy Supply account for RECs as intangible assets. PPL and PPL Energy Supply buy and/or sell RECs and also create RECs through owned renewable energy generation facilities. In any period, PPL and PPL Energy Supply can be a net purchaser or seller of RECs depending on their contractual obligations to purchase or deliver RECs and the production of RECs from their renewable energy generation facilities. The carrying value of RECs created from their renewable energy generation facilities is initially recorded at zero value and purchased RECs are initially recorded based on their purchase price. When RECs are consumed to satisfy an obligation to deliver RECs to meet a state's Renewable Portfolio Standard Obligation or when RECs are sold to third parties, they are removed from the Balance Sheet at their weighted-average carrying value. Since the economic benefits of RECs are not diminished until they are consumed, RECs are not amortized; rather, they are expensed when consumed or a gain or loss is recognized when sold. Such expense is included in "Energy purchases" on the Statements of Income. Gains and losses on the sale of RECs are included in "Other operation and maintenance" on the Statements of Income.
PPL, PPL Energy Supply, LKE, LG&E and KU account for emission allowances as intangible assets. PPL, PPL Energy Supply, LKE, 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. When 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; rather, 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 Statements of Income.
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. See Note 18 for a discussion of impairments related to certain intangible assets.
A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's carrying value is written down to its fair value. See Notes 15 and 18 for a discussion of the Corette coal-fired plant in Montana which was determined to be impaired in the fourth quarter of 2013.
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 Energy Supply's Brunner Island and Montour coal-fired generation plants in Pennsylvania were tested for impairment in the fourth quarter of 2013 and it was concluded that neither plant was impaired as of December 31, 2013. The recoverability test is very sensitive to forward energy and capacity price assumptions as well as forecasted operation and maintenance and capital spending. Therefore, a further decline in forecasted long-term energy or capacity prices or changes in environmental laws requiring additional capital or operations and maintenance costs, could negatively impact PPL Energy Supply's operations of these facilities and potentially result in future impairment charges for some or all of the carrying value of these plants. The carrying value of these assets was $2.7 billion as of December 31, 2013 ($1.4 billion for Brunner Island and $1.3 billion for Montour).
PPL, PPL Energy Supply, LKE, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, PPL Energy Supply's, LKE's, LG&E's and KU's reporting units are at the operating segment level.
PPL, PPL Energy Supply, LKE, LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a two-step quantitative test. If the qualitative evaluation (referred to as "step zero") is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the two-step quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a reporting unit is less than the carrying amount based on the step zero assessment.
If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, the implied fair value of goodwill must be calculated in the same manner as goodwill in a business combination. The fair value of a reporting unit is allocated to all assets and liabilities of that unit as if the reporting unit had been acquired in a business combination. The excess of the fair value of the reporting unit over the amounts assigned to its assets and liabilities is the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, goodwill is written down to its implied fair value.
PPL (for its U.K. Regulated and Kentucky Regulated segments), and individually, LKE, LG&E and KU elected to perform the qualitative step zero evaluation of goodwill in the fourth quarter of 2013 and determined that it was not more likely than not that the fair values of their reporting units were less than their carrying values.
PPL, for its Supply segment, and PPL Energy Supply elected to bypass step zero and quantitatively tested the goodwill of these reporting units for impairment in the fourth quarter of 2013 and no impairment was recognized.
Asset Retirement Obligations
PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. 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 remaining life of the associated long-lived asset. See Note 21 for additional information on AROs.
Compensation and Benefits
Defined Benefits (All Registrants)
Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets.
The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value.
PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the expected average remaining service of active plan participants. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the expected average remaining service period of active plan participants.
See Note 13 for a discussion of defined benefits.
Stock-Based Compensation
(All Registrants except LG&E and KU)
PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value method. 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 12 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Energy Supply, PPL Electric and LKE includes an allocation of PPL Services' expense.
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 and valuation allowances on deferred tax assets.
Significant management judgment is also required to determine the amount of benefit to be recognized in relation to an uncertain tax position. The Registrants use a two-step process to evaluate tax positions. The first step requires an entity to determine whether, based on the technical merits supporting a particular tax position, it is more likely than not (greater than a 50% chance) that the tax position will be sustained. This determination assumes that the relevant taxing authority will examine the tax position and is aware of all the relevant facts surrounding the tax position. The second step requires an entity to recognize in the financial statements the benefit of a tax position that meets the more-likely-than-not recognition criterion. The benefit recognized is measured at the largest amount of benefit that has a likelihood of realization, upon settlement, that exceeds 50%. The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements of the Registrants in future periods.
Deferred income taxes reflect the net future tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes, as well as the tax effects of net operating losses and tax credit carryforwards.
The Registrants record valuation allowances to reduce deferred tax assets to the amounts that are more likely than not to be realized. The Registrants consider the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies in initially recording and subsequently reevaluating the need for valuation allowances. If the Registrants determine that they are able to realize deferred tax assets in the future in excess of recorded net deferred tax assets, adjustments to the valuation allowances increase income by reducing tax expense in the period that such determination is made. Likewise, if the Registrants determine that they are not able to realize all or part of net deferred tax assets in the future, adjustments to the valuation allowances would decrease income by increasing tax expense in the period that such determination is made.
The Registrants defer investment tax credits when the credits are utilized and amortize the deferred amounts over the average lives of the related assets.
The Registrants recognize interest and penalties in "Income Taxes" on their Statements of Income.
See Note 5 for additional discussion regarding income taxes.
(All Registrants except PPL Energy Supply)
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 would be recorded under GAAP is deferred and included on the Balance Sheet in noncurrent "Regulatory assets" or "Regulatory liabilities."
(All Registrants except PPL)
The income tax provision for PPL Energy Supply, 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 Energy Supply, PPL Electric, LKE, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes. At December 31, the following intercompany tax receivables (payables) were recorded.
		2013			2012
PPL Energy Supply		$	44		$	-38
PPL Electric			-19			22
LKE			-28			-12
LG&E			-8			5
KU			-27			-15
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.
Other
Leases
(All Registrants)
The Registrants evaluate whether arrangements entered into contain leases for accounting purposes. See Note 11 for a discussion of arrangements under which PPL Energy Supply, LG&E and KU are lessees for accounting purposes.
Fuel, Materials and Supplies
(All Registrants)
Fuel, natural gas stored underground and materials and supplies are valued at the lower of cost or market 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.
(All Registrants except PPL Electric)
"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31.
					PPL						PPL Energy Supply						LKE					LG&E				KU
					2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
Fuel					$	305		$	284		$	163		$	135		$	141		$	149	$	64	$	61	$	77	$	88
Natural gas stored underground (a)						49			50			2			8			48			42		48		42
Materials and supplies						348			339			193			184			89			85		42		39		47		46
					$	702		$	673		$	358		$	327		$	278		$	276	$	154	$	142	$	124	$	134
(a)       The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.
Guarantees (All Registrants)
Generally, the initial measurement of a guarantee liability is the fair value of the guarantee at its inception. However, there are certain guarantees excluded from the scope of accounting guidance and other guarantees that are not subject to the initial recognition and measurement provisions of accounting guidance that only require disclosure. See Note 15 for further discussion of recorded and unrecorded guarantees.
Treasury Stock (PPL and PPL Electric)
PPL and PPL Electric restore all shares of common stock acquired to authorized but unissued shares of common stock upon acquisition.
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 translated at average exchange rates prevailing during the period included in PPL's results of operations. Adjustments resulting from foreign currency translation are recorded in AOCI.
Gains or losses relating to foreign currency transactions are recognized in "Other Income (Expense) - net" on the Statements of Income. See Note 17 for additional information.
New Accounting Guidance Adopted (All Registrants)
Improving Disclosures about Offsetting Balance Sheet Items
Effective January 1, 2013, the Registrants retrospectively adopted accounting guidance issued to enhance disclosures about derivative instruments that either (1) offset on the balance sheet or (2) are subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset on the balance sheet.
The adoption of this guidance resulted in enhanced disclosures but did not have a significant impact on the Registrants. See Note 19 for the new disclosures.
Testing Indefinite-Lived Intangible Assets for Impairment
Effective January 1, 2013, the Registrants prospectively adopted accounting guidance that allows an entity to elect the option to first make a qualitative evaluation about the likelihood of an impairment of an indefinite-lived intangible asset. If, based on this assessment, the entity determines that it is more likely than not that the fair value of the indefinite-lived intangible asset exceeds the carrying amount, a quantitative impairment test does not need to be performed. If the entity concludes otherwise, a quantitative impairment test must be performed by determining the fair value of the asset and comparing it with the carrying value. The entity would record an impairment charge, if necessary.
The adoption of this guidance did not have a significant impact on the Registrants.
Reporting Amounts Reclassified Out of AOCI
Effective January 1, 2013, the Registrants prospectively adopted accounting guidance issued to improve the reporting of reclassifications out of AOCI. The Registrants are required to provide information about the effects on net income of significant amounts reclassified out of AOCI by their respective statement of income line item, if the item is required to be reclassified to net income in its entirety. For items not reclassified to net income in their entirety, the Registrants are required to reference other disclosures that provide greater detail about these reclassifications.
The adoption of this guidance resulted in enhanced disclosures but did not have a significant impact on the Registrants. See Note 24 for the new disclosures.

Segment_and_Related_Informatio

Segment and Related Information	12 Months Ended
	Dec. 31, 2013
Segment and Related Information [Abstract]	'
Segment and Related Information	'
	2. Segment and Related Information
	(PPL)
	PPL is organized into four segments: U.K. Regulated, Kentucky Regulated, Pennsylvania Regulated and Supply. PPL's segments are split between its regulated and competitive businesses with its regulated businesses further segmented by geographic location.
	The U.K. Regulated segment consists of PPL Global which primarily includes WPD's regulated electricity distribution operations and certain costs, such as U.S. income taxes, administrative costs and allocated financing costs. The U.K. Regulated segment includes the operating results and assets of WPD Midlands since the April 1, 2011 acquisition date, recorded on a one-month lag. The U.K. Regulated segment is also allocated certain WPD Midlands acquisition-related costs and financing costs. See Note 10 for additional information regarding the acquisition.
	The Kentucky Regulated segment consists of the operations of LKE, which owns and operates regulated public utilities engaged in the generation, transmission, distribution and sale of electricity and distribution and sale of natural gas, representing primarily the activities of LG&E and KU. In addition, certain financing costs are allocated to the Kentucky Regulated segment.
	The Pennsylvania Regulated segment includes the regulated electricity delivery operations of PPL Electric. In addition, certain financing costs are allocated to the Pennsylvania Regulated segment.
	The Supply segment consists primarily of the activities of PPL Energy Supply's subsidiaries, PPL Generation and PPL EnergyPlus. PPL Generation owns and operates competitive domestic power plants to generate electricity and acquires and develops competitive domestic generation projects. PPL EnergyPlus markets and trades electricity, natural gas, and other energy-related products in competitive wholesale and retail markets. In addition, certain financing and other costs are allocated to the Supply segment.
	"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.
	In 2013, costs included in the Corporate and Other category increased, as anticipated, primarily due to an increase in financing at PPL Capital Funding not directly attributable to a particular segment. PPL's growth in rate-regulated businesses provides the organization an enhanced corporate-level financing alternative, through PPL Capital Funding, that further enables PPL to cost-effectively support targeted credit profiles across all of PPL's rated companies. As a result, PPL plans to further utilize PPL Capital Funding in addition to continued direct financing by the operating companies. The financing costs associated primarily with PPL Capital Funding's new securities issuances, with certain exceptions including the remarketing of the debt component of the Equity Units, have not been directly assigned or allocated to any segment and generally have been reflected in Corporate and Other in 2013.
	Financial data for the segments are:
	Income Statement Data						2013			2012			2011
	Revenues from external customers by product
			U.K. Regulated
				Utility service (a)			$	2,359		$	2,289		$	1,618
				Energy-related businesses				44			47			35
					Total			2,403			2,336			1,653
			Kentucky Regulated
				Utility service (a)				2,976			2,759			2,793
			Pennsylvania Regulated
				Utility service (a)				1,866			1,760			1,881
			Supply
				Energy (b)				4,075			4,970			5,938
				Energy-related businesses				527			461			472
					Total			4,602			5,431			6,410
			Corporate and Other					13
	Total							11,860			12,286			12,737
	Intersegment electric revenues
			Pennsylvania Regulated					4			3			11
			Supply (c)					51			79			26
	Depreciation
			U.K. Regulated					300			279			218
			Kentucky Regulated					334			346			334
			Pennsylvania Regulated					178			160			146
			Supply					318			289			245
			Corporate and Other					31			26			17
	Total							1,161			1,100			960
	Amortization (d)
			U.K. Regulated					19			15			83
			Kentucky Regulated					22			27			27
			Pennsylvania Regulated					19			18			7
			Supply					156			126			137
			Corporate and Other					6
	Total							222			186			254
	Unrealized (gains) losses on derivatives and other hedging activities (b)
			U.K. Regulated					44			52			-8
			Kentucky Regulated					12			11			9
			Supply					180			-36			-315
	Total							236			27			-314
	Interest Expense
			U.K. Regulated					425			421			391
			Kentucky Regulated					212			219			217
			Pennsylvania Regulated					108			99			98
			Supply					228			222			192
			Corporate and Other					33
	Total							1,006			961			898
	Income from Continuing Operations Before Income Taxes
			U.K. Regulated					993			953			358
			Kentucky Regulated					484			263			349
			Pennsylvania Regulated					317			204			257
			Supply (b) (g)					-428			662			1,237
			Corporate and Other					-57
	Total							1,309			2,082			2,201
	Income Taxes (e)
		U.K. Regulated					71			150			33
		Kentucky Regulated					179			80			127
		Pennsylvania Regulated					108			68			68
		Supply					-157			247			463
		Corporate and Other					-21
Total							180			545			691
Deferred income taxes and investment tax credits (f)
		U.K. Regulated					-45			26			-39
		Kentucky Regulated					254			136			218
		Pennsylvania Regulated					127			114			106
		Supply					-296			150			299
		Corporate and Other					32
Total							72			426			584
Net Income Attributable to PPL Shareowners
		U.K. Regulated					922			803			325
		Kentucky Regulated					307			177			221
		Pennsylvania Regulated					209			132			173
		Supply (b) (g)					-272			414			776
		Corporate and Other					-36
	Total					$	1,130		$	1,526		$	1,495
Cash Flow Data							2013			2012			2011
Expenditures for long-lived assets
		U.K. Regulated				$	1,280		$	1,016		$	862
		Kentucky Regulated					1,434			768			465
		Pennsylvania Regulated					942			633			490
		Supply					568			736			739
		Corporate and Other					59
Total						$	4,283		$	3,153		$	2,556
			As of December 31,
			2013			2012
Balance Sheet Data
Total Assets
	U.K. Regulated		$	15,895		$	14,073
	Kentucky Regulated			12,016			10,670
	Pennsylvania Regulated			6,846			6,023
	Supply			11,408			12,868
	Corporate and Other (h)			94
Total			$	46,259		$	43,634
				2013			2012			2011
Geographic Data
Revenues from external customers
		U.K.		$	2,403		$	2,336		$	1,653
		U.S.			9,457			9,950			11,084
Total				$	11,860		$	12,286		$	12,737
			As of December 31,
			2013			2012
Long-Lived Assets
	U.K.		$	11,145		$	9,951
	U.S.			22,638			20,776
Total			$	33,783		$	30,727
(a)       See Note 1 for additional information on Utility Revenue.
(b)       Includes unrealized gains and losses from economic activity. See Note 19 for additional information.
(c)       See "PLR Contracts/Purchase of Accounts Receivable" in Note 16 for a discussion of the basis of accounting between reportable segments.
(d)       Represents non-cash expense items that include amortization of nuclear fuel, regulatory assets, debt discounts and premiums, debt issuance costs, emission allowances and RECs.
(e)       Represents both current and deferred income taxes, including investment tax credits.
(f)       Represents a non-cash expense item that is also included in "Income Taxes."
(g)       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.
(h)       Primarily consists of unallocated items, including cash, PP&E and the elimination of inter-segment transactions.
(All Registrants except PPL)
PPL Energy Supply, PPL Electric, LKE, LG&E and KU each operate within a single reportable segment.

Preferred_Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2013
Preferred Securities [Line Items]	'
Preferred Securities	'
	3. Preferred Securities
	(PPL)
	In June 2012, PPL Electric redeemed all of its preference stock at par value, without premium ($250 million in the aggregate). Related dividend requirements of $4 million for 2012 and $16 million for 2011 have been included in "Net Income Attributable to Noncontrolling Interests" on the Statements of Income.
	PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2013, 2012, or 2011.
	(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 2013, 2012, or 2011. Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference stock. PPL Electric had 2.5 million shares of 6.25% Series Preference Stock (Preference Shares) issued and outstanding at December 31, 2011. In June 2012, PPL Electric redeemed all 2.5 million shares of its outstanding Preference Shares, par value of $100 per share. The price paid for the redemption was the par value, without premium ($250 million in the aggregate).
	(LG&E)
	LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2013, 2012 or 2011.
	(KU)
	KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2013, 2012 or 2011.
PPL Electric Utilities Corp [Member]	'
Preferred Securities [Line Items]	'
Preferred Securities	'
	3. Preferred Securities
	(PPL)
	In June 2012, PPL Electric redeemed all of its preference stock at par value, without premium ($250 million in the aggregate). Related dividend requirements of $4 million for 2012 and $16 million for 2011 have been included in "Net Income Attributable to Noncontrolling Interests" on the Statements of Income.
	PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2013, 2012, or 2011.
	(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 2013, 2012, or 2011. Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference stock. PPL Electric had 2.5 million shares of 6.25% Series Preference Stock (Preference Shares) issued and outstanding at December 31, 2011. In June 2012, PPL Electric redeemed all 2.5 million shares of its outstanding Preference Shares, par value of $100 per share. The price paid for the redemption was the par value, without premium ($250 million in the aggregate).
	(LG&E)
	LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2013, 2012 or 2011.
	(KU)
	KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2013, 2012 or 2011.
Louisville Gas And Electric Co [Member]	'
Preferred Securities [Line Items]	'
Preferred Securities	'
	3. Preferred Securities
	(PPL)
	In June 2012, PPL Electric redeemed all of its preference stock at par value, without premium ($250 million in the aggregate). Related dividend requirements of $4 million for 2012 and $16 million for 2011 have been included in "Net Income Attributable to Noncontrolling Interests" on the Statements of Income.
	PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2013, 2012, or 2011.
	(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 2013, 2012, or 2011. Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference stock. PPL Electric had 2.5 million shares of 6.25% Series Preference Stock (Preference Shares) issued and outstanding at December 31, 2011. In June 2012, PPL Electric redeemed all 2.5 million shares of its outstanding Preference Shares, par value of $100 per share. The price paid for the redemption was the par value, without premium ($250 million in the aggregate).
	(LG&E)
	LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2013, 2012 or 2011.
	(KU)
	KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2013, 2012 or 2011.
Kentucky Utilities Co [Member]	'
Preferred Securities [Line Items]	'
Preferred Securities	'
	3. Preferred Securities
	(PPL)
	In June 2012, PPL Electric redeemed all of its preference stock at par value, without premium ($250 million in the aggregate). Related dividend requirements of $4 million for 2012 and $16 million for 2011 have been included in "Net Income Attributable to Noncontrolling Interests" on the Statements of Income.
	PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2013, 2012, or 2011.
	(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 2013, 2012, or 2011. Prior to October 31, 2013, PPL Electric was authorized to issue up to 10 million shares of preference stock. PPL Electric had 2.5 million shares of 6.25% Series Preference Stock (Preference Shares) issued and outstanding at December 31, 2011. In June 2012, PPL Electric redeemed all 2.5 million shares of its outstanding Preference Shares, par value of $100 per share. The price paid for the redemption was the par value, without premium ($250 million in the aggregate).
	(LG&E)
	LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2013, 2012 or 2011.
	(KU)
	KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2013, 2012 or 2011.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	4. Earnings Per Share
	(PPL)
	Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by incremental shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares as calculated using the Treasury Stock method or If-Converted Method, as applicable. Incremental non-participating securities that have a dilutive impact are detailed in the table below.
	Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31 used in the EPS calculation are:
					2013		2012		2011
	Income (Numerator)
	Income from continuing operations after income taxes attributable to PPL shareowners				$	1,128	$	1,532	$	1,493
	Less amounts allocated to participating securities					6		8		6
	Less issuance costs on subsidiary's preferred securities redeemed							6
	Income from continuing operations after income taxes available to PPL common
		shareowners - Basic				1,122		1,518		1,487
	Plus interest charges (net of tax) related to Equity Units (a)					44
	Income from continuing operations after income taxes available to PPL common
		shareowners - Diluted			$	1,166	$	1,518	$	1,487
	Income (loss) from discontinued operations (net of income taxes) available to PPL
		common shareowners - Basic and Diluted			$	2	$	-6	$	2
	Net income attributable to PPL shareowners				$	1,130	$	1,526	$	1,495
	Less amounts allocated to participating securities					6		8		6
	Less issuance costs on subsidiary's preferred securities redeemed							6
	Net income available to PPL common shareowners - Basic					1,124		1,512		1,489
	Plus interest charges (net of tax) related to Equity Units					44
	Net income available to PPL common shareowners - Diluted				$	1,168	$	1,512	$	1,489
	Shares of Common Stock (Denominator)
	Weighted-average shares - Basic EPS					608,983		580,276		550,395
	Add incremental non-participating securities:
			Share-based payment awards (b)			1,062		563		400
			Equity Units (a)			52,568
			Forward sale agreements and purchase contracts (b)			460		787		157
	Weighted-average shares - Diluted EPS					663,073		581,626		550,952
	Basic EPS
	Available to PPL common shareowners:
			Income from continuing operations after income taxes		$	1.85	$	2.62	$	2.7
			Income (loss) from discontinued operations (net of income taxes)					-0.01		0.01
			Net Income		$	1.85	$	2.61	$	2.71
	Diluted EPS
	Available to PPL common shareowners:
			Income from continuing operations after income taxes		$	1.76	$	2.61	$	2.7
			Income (loss) from discontinued operations (net of income taxes)					-0.01
			Net Income		$	1.76	$	2.6	$	2.7
	(a)       In 2013, the If-Converted Method was applied to the Equity Units prior to settlement.
	(b)       The Treasury Stock Method was applied to non-participating share-based payment awards, forward sale agreements and the 2010 Purchase Contracts for 2012 and 2011.
	For the year ended December 31, PPL issued common stock related to stock-based compensation plans, ESOP and DRIP as follows:
	(Shares in thousands)		2013
	Stock-based compensation plans (a)			1,552
	ESOP			275
	DRIP			549
	(a)       Includes stock options exercised, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.
	For the years ended December 31, the following were excluded from the computations of diluted EPS because the effect would have been antidilutive.
	(Shares in thousands)		2013		2012		2011
	Stock options			4,446		5,293		5,084
	Performance units			55		58		2
	Restricted stock units			29
	See Note 7 for additional information on the 2011 and 2010 Equity Units, including the issuance of PPL common stock to settle the 2010 Purchase Contracts, the April and May 2013 settlements of forward sale agreements and information on the repurchase of shares of PPL common stock that offset the 2013 issuances of common stock under stock-based compensation plans, ESOP and DRIP.

Income_and_Other_Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2013
Income and Other Taxes [Abstract]	'
Income and Other Taxes	'
	5. Income and Other Taxes
	(PPL)
	"Income from Continuing Operations Before Income Taxes" included the following.
				2013			2012			2011
	Domestic income			$	196		$	994		$	1,715
	Foreign income				1,113			1,088			486
		Total		$	1,309		$	2,082		$	2,201
	Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes and the tax effects of net operating loss and tax credit carryforwards. The provision for PPL's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles of the applicable jurisdiction. See Notes 1 and 6 for additional information.
	Net deferred tax assets have been recognized based on management's estimates of future taxable income for the U.S. and certain foreign jurisdictions in which PPL's operations have historically been profitable.
	Significant components of PPL's deferred income tax assets and liabilities were as follows:
					2013			2012
	Deferred Tax Assets
		Deferred investment tax credits			$	137		$	130
		Regulatory obligations				144			124
		Accrued pension costs				140			276
		Federal loss carryforwards				331			524
		State loss carryforwards				304			305
		Federal and state tax credit carryforwards				332			287
		Foreign capital loss carryforwards				467			525
		Foreign loss carryforwards				6			6
		Foreign - pensions				202			254
		Foreign - regulatory obligations				26			27
		Foreign - other				12			16
		Contributions in aid of construction				137			134
		Domestic - other				211			239
		Valuation allowances				-663			-706
			Total deferred tax assets			1,786			2,141
	Deferred Tax Liabilities
		Domestic plant - net				4,073			3,967
		Taxes recoverable through future rates				151			141
		Unrealized gain on qualifying derivatives				37			122
		Other regulatory assets				244			319
		Reacquired debt costs				34			40
		Foreign plant - net				859			937
		Domestic - other				78			66
			Total deferred tax liabilities			5,476			5,592
	Net deferred tax liability				$	3,690		$	3,451
	At December 31, PPL had the following loss and tax credit carryforwards.
				2013				Expiration
	Loss carryforwards
		Federal net operating losses (a)		$	952			2028-2032
		State net operating losses (a) (b)			5,011			2014-2033
		State capital losses (c)			125			2014-2016
		Foreign net operating losses (d)			30			Indefinite
		Foreign capital losses (e)			2,333			Indefinite
	Credit carryforwards
		Federal investment tax credit			245			2025-2033
		Federal alternative minimum tax credit			32			Indefinite
		Federal foreign tax credit			17			2017-2023
		Federal - other			35			2016-2033
		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 $185 million has been recorded against the deferred tax assets for these losses.
	(c)       A valuation allowance of $5 million has been recorded against the deferred tax assets for these losses.
	(d)       A valuation allowance of $6 million has been recorded against the deferred tax assets for these losses.
	(e)       A valuation allowance of $467 million has been recorded against the deferred tax assets for these losses.
	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
	2013		$	706		$	29						$	72	(a)	$	663
	2012			724			18		$	10				46	(a)		706
2011			464			190			112	(b)			42	(a)		724
(a)       The reductions of the U.K. statutory income tax rate in 2013, 2012 and 2011 resulted in $67 million, $46 million and $35 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 of 2013, 2012 and 2011.
(b)       Primarily related to a $101 million valuation allowance that was recorded against certain deferred tax assets as a result of the 2011 acquisition of WPD Midlands. See Note 10 for additional information on the acquisition.
PPL Global does not pay or 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 facilities 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 considered indefinitely reinvested at December 31, 2013 and 2012 were $2.9 billion and $2.0 billion. 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 amount of additional taxes that could be payable on these foreign earnings in the event of repatriation to the U.S.
Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows:
					2013			2012			2011
Income Tax Expense (Benefit)
	Current - Federal				$	-75					$	54
	Current - State					1		$	-2			-20
	Current - Foreign					181			121			73
			Total Current Expense (Benefit)			107			119			107
	Deferred - Federal					73			553			558
	Deferred - State					45			103			127
	Deferred - Foreign					-53			35			-23
			Total Deferred Expense (Benefit), excluding operating loss carryforwards			65			691			662
	Investment tax credit, net - Federal					-10			-10			-10
	Tax expense (benefit) of operating loss carryforwards
		Deferred - Federal (a)				36			-195			-30
		Deferred - State				-18			-60			-38
			Total Tax Expense (Benefit) of Operating Loss Carryforwards			18			-255			-68
	Total income taxes from continuing operations				$	180		$	545		$	691
	Total income tax expense - Federal				$	24		$	348		$	572
	Total income tax expense (benefit) - State					28			41			69
	Total income tax expense - Foreign					128			156			50
			Total income taxes from continuing operations		$	180		$	545		$	691
(a)       A 2012 Federal income tax return adjustment was recorded in 2013 related to a reduction in the 2012 NOL recorded in the filed return. The reduction was primarily due to PPL's decision, at the time of filing, to utilize regular modified accelerated cost recovery system (MACRS) depreciation rates for certain non-regulated assets otherwise eligible for bonus tax depreciation.
In the table above, the following income tax expense (benefits) are excluded from income taxes from continuing operations.
				2013			2012			2011
Discontinued operations				$	1		$	-4		$	2
Stock-based compensation recorded to Additional Paid-in Capital					-2			-1			3
Issuance costs of Purchase Contracts recorded to Additional Paid-in Capital											-9
Valuation allowance on state deferred taxes related to issuance costs of Purchase Contracts
	recorded to Additional Paid-in Capital				-2						4
Other comprehensive income					159			-526			-144
Valuation allowance on state deferred taxes recorded to other comprehensive income					-7						7
		Total		$	149		$	-531		$	-137
					2013			2012			2011
Reconciliation of Income Tax Expense
	Federal income tax on Income from Continuing Operations Before Income Taxes at
		statutory tax rate - 35%			$	458		$	729		$	770
Increase (decrease) due to:
	State income taxes, net of federal income tax benefit					-7			27			63
	State valuation allowance adjustments (a)					24			13			36
	Impact of lower U.K. income tax rates (b)					-129			-110			-33
	U.S. income tax on foreign earnings - net of foreign tax credit (c)					9			26			-26
	Federal and state tax reserves adjustments (d)					-43			-1			39
	Foreign tax reserves adjustments (e)					-2			-5			-141
	Federal and state income tax return adjustments (a) (f)					-5			16			-17
	Foreign income tax return adjustments					-4			-6
	Impact of the U.K. Finance Acts on deferred tax balances (b)					-97			-75			-69
	Federal income tax credits (g)					-9			-12			-13
	Depreciation not normalized (a)					-8			-11			-20
	Foreign valuation allowance adjustments (e)											147
	State deferred tax rate change (h)					15			-19			-26
	Net operating loss carryforward adjustments (i)								-9
	Intercompany interest on U.K. financing entities (j)					-10			-9			-8
	Other					-12			-9			-11
			Total increase (decrease)			-278			-184			-79
Total income taxes from continuing operations					$	180		$	545		$	691
Effective income tax rate						13.80%			26.20%			31.40%
(a)       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.
During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. Due to the decrease in projected taxable income related to bonus depreciation and a decrease in projected future taxable income, PPL recorded $43 million in state deferred income tax expense related to deferred tax valuation allowances during 2011.
Additionally, the 100% Pennsylvania bonus depreciation deduction created a current state income tax benefit for the flow-through impact of Pennsylvania regulated state tax depreciation. The federal provision for 100% bonus depreciation generally applies to property placed into service before January 1, 2012. The placed in-service deadline was extended to January 1, 2013 for property that had a cost in excess of $1 million, had a production period longer than one year and had a tax life of at least ten years. PPL's tax deduction for 100% bonus regulated tax depreciation was zero in 2013 and was significantly lower in 2012 than in 2011.
(b)       The U.K. Finance Act 2013, enacted 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 related to both rate decreases.
The U.K. Finance Act 2012, enacted in July 2012, reduced the U.K. statutory income tax rate from 25% to 24% retroactive to April 1, 2012 and from 24% to 23% effective April 1, 2013. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2012 related to both rate decreases.
The U.K. Finance Act 2011, enacted in July 2011, reduced the U.K. statutory income tax rate from 27% to 26% retroactive to April 1, 2011 and from 26% to 25% effective April 1, 2012. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2011 related to both rate decreases.
(c)       During 2013, PPL recorded $25 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 reflected on an amended 2010 U.S. tax return.
During 2012, PPL recorded a $23 million adjustment to federal income tax expense related to the recalculation of 2010 U.K. earnings and profits.
During 2011, PPL recorded a $28 million federal income tax benefit related to U.K. pension contributions.
(d)       In 1997, the U.K. imposed a Windfall Profits Tax (WPT) on privatized utilities, including WPD. PPL filed its federal income tax returns for years subsequent to its 1997 and 1998 claims for refund on the basis that the U.K. WPT was creditable. In September 2010, the U.S. Tax Court (Tax Court) ruled in PPL's favor in a dispute with the IRS, concluding that the U.K. WPT is a creditable tax for U.S. tax purposes. As a result, and with the finalization of other issues, PPL recorded a $42 million tax benefit in 2010. In January 2011, the IRS appealed the Tax Court's decision to the U.S. Court of Appeals for the Third Circuit (Third Circuit). In December 2011, the Third Circuit issued its opinion reversing the Tax Court's decision, holding that the U.K. WPT is not a creditable tax. As a result of the Third Circuit's adverse determination, PPL recorded a $39 million expense in 2011. In June 2012, the U.S. Court of Appeals for the Fifth Circuit issued a contrary opinion in an identical case involving another company. In July 2012, PPL filed a petition for a writ of certiorari seeking U.S. Supreme Court review of the Third Circuit's opinion. The Supreme Court granted PPL's petition and oral argument was held in February 2013. On May 20, 2013, the Supreme Court reversed the Third Circuit's opinion and ruled that the WPT is a creditable tax. As a result of the Supreme Court ruling, PPL recorded a tax benefit of $44 million during 2013, of which $19 million relates to interest.
PPL recorded a tax benefit of $7 million during 2013 and $6 million during 2012 and 2011 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization is zero.
(e)       During 2012, PPL recorded a foreign tax benefit following resolution of a U.K. tax issue related to interest expense.
During 2011, WPD reached an agreement with HMRC related to the amount of the capital losses that resulted from prior years' restructuring in the U.K. and recorded a $147 million foreign tax benefit for the reversal of tax reserves related to the capital losses. Additionally, WPD recorded a $147 million valuation allowance for the amount of capital losses that, more likely than not, will not be utilized.
(f)       During 2012, PPL recorded $16 million in federal and state income tax expense related to the filing of the 2011 federal and state income tax returns. Of this amount, $5 million relates to the reversal of prior years' state income tax benefits related to regulated depreciation. PPL changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year. In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates for network assets. The IRS guidance provided a safe harbor method of determining whether the repair expenditures for electric transmission and distribution property can be currently deducted for tax purposes. PPL adopted the safe harbor method with the filing of its 2011 federal income tax return.
During 2011, PPL recorded $17 million in federal and state tax benefits related to the filing of the 2010 federal and state income tax returns. Of this amount, $7 million in tax benefits related to an additional domestic manufacturing deduction resulting from revised bonus depreciation amounts and $3 million in tax benefits related to the flow-through impact of Pennsylvania regulated state tax depreciation.
(g)       During 2013, 2012 and 2011, PPL recorded a deferred tax benefit related to investment tax credits on progress expenditures related to hydroelectric plant expansions. See Note 8 for additional information.
(h)       During 2013, 2012 and 2011, 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.
(i)       During 2012, PPL recorded adjustments to deferred taxes related to net operating loss carryforwards of LKE based on income tax return adjustments.
(j)       During 2013, 2012 and 2011, PPL recorded income tax benefits related to interest expense on intercompany loans.
				2013			2012			2011
Taxes, other than income
	State gross receipts			$	135		$	135		$	140
	State utility realty				2			2			-9
	State capital stock				2			7			18
	Foreign property				147			147			113
	Domestic property and other				78			75			64
	Total			$	364		$	366		$	326
(PPL Energy Supply)
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.
Net deferred tax assets have been recognized based on management's estimates of future taxable income for the U.S. jurisdictions in which PPL Energy Supply's operations have historically been profitable.
Significant components of PPL Energy Supply's deferred income tax assets and liabilities were as follows:
				2013			2012
Deferred Tax Assets
	Deferred investment tax credits			$	84		$	75
	Accrued pension costs				39			94
	Federal loss carryforwards				28			51
	Federal tax credit carryforwards				131			113
	State loss carryforwards				80			79
	Other				69			68
	Valuation allowances				-78			-74
		Total deferred tax assets			353			406
Deferred Tax Liabilities
	Plant - net				1,392			1,579
	Unrealized gain on qualifying derivatives				38			173
	Other				46			44
		Total deferred tax liabilities			1,476			1,796
Net deferred tax liability				$	1,123		$	1,390
At December 31, PPL Energy Supply had the following loss and tax credit carryforwards.
			2013				Expiration
Loss carryforwards
	Federal net operating losses		$	80			2031-2032
	State net operating losses (a)			1,204			2014-2033
Credit carryforwards
	Federal investment tax credit			120			2031-2033
	Federal - other			9			2031-2033
(a) A valuation allowance of $78 million has been recorded against the deferred tax assets for these losses.
Federal alternative minimum tax credit carryforwards were insignificant at December 31, 2013.
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:
					Additions
		Balance at						Charged to							Balance
		Beginning			Charged			Other							at End
		of Period			to Income			Accounts				Deductions			of Period
2013		$	74		$	4									$	78
2012			72			2										74
2011			408			22						$	358	(a)		72
(a)       During 2011, PPL Energy Supply distributed its membership interest in PPL Global to PPL Energy Funding. See Note 9 for additional information.
Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows:
					2013			2012			2011
Income Tax Expense (Benefit)
	Current - Federal				$	134		$	89		$	139
	Current - State					21			22			-12
			Total Current Expense (Benefit)			155			111			127
	Deferred - Federal					-287			193			251
	Deferred - State					-27			10			70
			Total Deferred Expense (Benefit), excluding operating loss carryforwards			-314			203			321
	Investment tax credit, net - federal					-5			-2			-3
	Tax expense (benefit) of operating loss carryforwards
		Deferred - Federal (a)				22			-48
		Deferred - State							-1
			Total Tax Expense (Benefit) of Operating Loss Carryforwards			22			-49
	Total income taxes from continuing operations (b)				$	-142		$	263		$	445
	Total income tax expense - Federal				$	-136		$	232		$	387
	Total income tax expense (benefit) - State					-6			31			58
			Total income taxes from continuing operations (b)		$	-142		$	263		$	445
(a)        A 2012 federal income tax return adjustment was recorded in 2013 related to a reduction in the 2012 NOL recorded in the filed return. The reduction was primarily due to PPL's decision, at the time of filing, to utilize regular MACRS depreciation rates for certain non-regulated assets otherwise eligible for bonus tax depreciation.
(b)       Excludes current and deferred federal, state and foreign tax expense (benefit) recorded to Discontinued Operations of $3 million in 2011. Also, excludes federal, state and foreign tax expense (benefit) recorded to OCI of $47 million in 2013, $(267) million in 2012 and $(83) million in 2011. The deferred tax benefit of operating loss carryforwards was insignificant for 2011.
					2013			2012			2011
Reconciliation of Income Tax Expense
	Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at
		statutory tax rate - 35%			$	-130		$	258		$	424
Increase (decrease) due to:
	State income taxes, net of federal income tax benefit					-22			33			60
	State valuation allowance adjustments (a)					4			2			22
	State deferred tax rate change (b)					15			-19			-26
	Federal and state tax reserves adjustments (c)					6			-2			2
	Federal and state income tax return adjustments (d)					-1			4			-22
	Federal income tax credits (e)					-8			-12			-12
	Other					-6			-1			-3
			Total increase (decrease)			-12			5			21
Total income taxes from continuing operations					$	-142		$	263		$	445
Effective income tax rate						38.30%			35.60%			36.70%
(a)       During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. Due to the decrease in projected taxable income related to bonus depreciation and a decrease in projected future taxable income, PPL Energy Supply recorded state deferred income tax expense related to deferred tax valuation allowances during 2011.
(b)       During 2013, 2012 and 2011, PPL Energy Supply 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. .
(c)       During 2013, PPL Energy Supply reversed $3 million in tax benefits related to a 2008 change in method of accounting for certain expenditures for tax purposes and recorded $4 million in federal tax expense related to differences in over (under) payment interest rates applied to audit claims as a result of the U.S. Supreme Court decision related to Windfall Profits Tax.
(d)       During 2011, PPL Energy Supply recorded federal and state tax benefits related to the filing of the 2010 federal and state income tax returns. Of this amount, $7 million in tax benefits related to an additional domestic manufacturing deduction resulting from revised bonus depreciation amounts.
(e)       During 2013, 2012 and 2011, PPL Energy Supply recorded a deferred tax benefit related to investment tax credits on progress expenditures related to hydroelectric plant expansions. See Note 8 for additional information.
				2013			2012			2011
Taxes, other than income
	State gross receipts			$	37		$	35		$	31
	State capital stock				1			5			12
	Property and other				28			29			28
		Total		$	66		$	69		$	71
(PPL Electric)
The provision for PPL Electric's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the PUC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulated liabilities" on the Balance Sheets.
Significant components of PPL Electric's deferred income tax assets and liabilities were as follows.
				2013			2012
Deferred Tax Assets
	Accrued pension costs			$	42		$	81
	Contributions in aid of construction				109			106
	Regulatory obligations				38			24
	State loss carryforwards				35			39
	Federal loss carryforwards				72			81
	Other				45			46
		Total deferred tax assets			341			377
Deferred Tax Liabilities
	Electric utility plant - net				1,366			1,229
	Taxes recoverable through future rates				129			122
	Reacquired debt costs				23			27
	Other regulatory assets				129			174
	Other				8			12
		Total deferred tax liabilities			1,655			1,564
Net deferred tax liability				$	1,314		$	1,187
At December 31, PPL Electric had the following loss carryforwards.
			2013				Expiration
Loss carryforwards
	Federal net operating losses		$	206			2031-2032
	State net operating losses			534			2030-2032
Credit carryforwards were insignificant at December 31, 2013.
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:
					2013			2012			2011
Income Tax Expense (Benefit)
	Current - Federal				$	-15		$	-28		$	-25
	Current - State					-4			-18			-13
			Total Current Expense (Benefit)			-19			-46			-38
	Deferred - Federal					109			162			123
	Deferred - State					16			42			25
			Total Deferred Expense (Benefit), excluding operating loss carryforwards			125			204			148
	Investment tax credit, net - Federal					-1			-1			-2
	Tax expense (benefit) of operating loss carryforwards
		Deferred - Federal				4			-72			-12
		Deferred - State				-1			-17			-28
			Total Tax Expense (Benefit) of Operating Loss Carryforwards			3			-89			-40
	Total income tax expense				$	108		$	68		$	68
	Total income tax expense - Federal				$	97		$	61		$	84
	Total income tax expense (benefit) - State					11			7			-16
			Total income tax expense		$	108		$	68		$	68
					2013			2012			2011
Reconciliation of Income Taxes
	Federal income tax on Income Before Income Taxes at statutory tax rate - 35%				$	111		$	71		$	90
Increase (decrease) due to:
	State income taxes, net of federal income tax benefit					16			9			12
	Amortization of investment tax credit					-1			-1			-2
	Federal and state tax reserves adjustments (a)					-9			-8			-9
	Federal and state income tax return adjustments (b)					-1			7			-4
	Depreciation not normalized (c)					-6			-8			-17
	Other					-2			-2			-2
			Total increase (decrease)			-3			-3			-22
Total income tax expense					$	108		$	68		$	68
Effective income tax rate						34.10%			33.30%			26.50%
(a)       PPL Electric recorded a tax benefit of $7 million during 2013 and $6 million during 2012 and 2011 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization is zero.
(b)       PPL Electric changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year. In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates for network assets. The IRS guidance provided a safe harbor method of determining whether the repair expenditures for electric transmission and distribution property can be currently deducted for tax purposes. PPL Electric adopted the safe harbor method with the filing of its 2011 federal income tax return and recorded a $5 million adjustment to federal and state income tax expense resulting from the reversal of prior years' state income tax benefits related to regulated depreciation.
During 2011, PPL Electric recorded a $5 million federal and state income tax benefit as a result of filing its 2010 federal and state income tax returns. Of this amount, $3 million in tax benefits related to the flow-through impact of Pennsylvania regulated 100% bonus tax depreciation.
(c)       During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. The 100% Pennsylvania bonus depreciation deduction created a current state income tax benefit for the flow-through impact of Pennsylvania regulated state tax depreciation. The federal provision for 100% bonus depreciation generally applies to property placed into service before January 1, 2012. The placed in service deadline was extended to January 1, 2013 for property that had a cost in excess of $1 million, had a production period longer that one year and had a tax life of at least ten years. PPL Electric's tax deduction for 100% bonus depreciation was zero in 2013 and was significantly lower in 2012 than in 2011.
				2013			2012			2011
Taxes, other than income
	State gross receipts			$	98		$	101		$	109
	State utility realty (a)				2			2			-10
	State capital stock				1			1			4
	Property and other				2			1			1
		Total		$	103		$	105		$	104
(a)       2011 includes PURTA tax that was refunded to PPL Electric customers in 2011.
(LKE)
The provision for LKE's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC, VSCC, 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 LKE's deferred income tax assets and liabilities were as follows:
				2013			2012
Deferred Tax Assets
	Net operating loss carryforward			$	222		$	376
	Tax credit carryforwards				179			170
	Regulatory liabilities				107			99
	Accrued pension costs				26			42
	Capital loss carryforward				4			5
	Income taxes due to customers				23			26
	Deferred investment tax credits				52			54
	Other				57			41
	Valuation allowances				-4			-5
		Total deferred tax assets			666			808
Deferred Tax Liabilities
	Plant - net				1,327			1,171
	Regulatory assets				133			152
	Other				12			13
		Total deferred tax liabilities			1,472			1,336
Net deferred tax liability				$	806		$	528
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.
			2013			Expiration
Loss carryforwards
	Federal net operating losses		$	523		2028-2032
	State net operating losses			1,024		2028-2032
	State capital losses			106		2014-2016
Credit carryforwards
	Federal investment tax credit			125		2025-2028
	Federal alternative minimum tax credit			28		Indefinite
	Federal - other			26		2016-2033
	State - other			9		2022
Changes in deferred tax valuation allowances were:
		Balance at										Balance
		Beginning										at End
		of Period			Additions			Deductions				of Period
2013		$	5					$	1	(a)		$	4
2012			5										5
2011			6						1	(a)			5
(a)       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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were:
				2013			2012			2011
Income Tax Expense (Benefit)
	Current - Federal			$	-59		$	-32		$	-71
	Current - State				10			2			6
			Total Current Expense (Benefit)		-49			-30			-65
	Deferred - Federal				244			185			208
	Deferred - State				20			15			16
			Total Deferred Expense, excluding benefits of operating loss carryforwards		264			200			224
	Investment tax credit, net - Federal				-4			-6			-6
	Tax benefit of operating loss carryforwards
		Deferred - Federal			-4			-46
		Deferred - State			-1			-12
			Total Tax Benefit of Operating Loss Carryforwards		-5			-58
	Total income tax expense from continuing operations (a)			$	206		$	106		$	153
	Total income tax expense - Federal			$	177		$	101		$	131
	Total income tax expense - State				29			5			22
			Total income tax expense from continuing operations (a)	$	206		$	106		$	153
(a)       Excludes current and deferred federal and state tax expense (benefit) recorded to Discontinued Operations of $1 million in 2013, $(4) million in 2012, and $(1) million in 2011. Also, excludes deferred federal and state tax expense (benefit) recorded to OCI of $18 million in 2013, $(12) million in 2012 and $(1) million in 2011.
					2013			2012			2011
Reconciliation of Income Taxes
	Federal income tax on Income Before Income Taxes at
		statutory tax rate - 35%			$	193		$	116		$	147
Increase (decrease) due to:
	State income taxes, net of federal income tax benefit					20			6			15
	Amortization of investment tax credit					-4			-6			-5
	Net operating loss carryforward (a)								-9
	Other					-3			-1			-4
			Total increase (decrease)			13			-10			6
Total income tax expense from continuing operations					$	206		$	106		$	153
Effective income tax rate						37.40%			32.00%			36.50%
(a)       During 2012, LKE recorded adjustments to deferred taxes related to net operating loss carryforwards based on income tax return adjustments.
					2013			2012			2011
Taxes, other than income
	Property and other				$	48		$	46		$	37
			Total		$	48		$	46		$	37
(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:
				2013			2012
Deferred Tax Assets
	Regulatory liabilities			$	59		$	54
	Deferred investment tax credits				15			16
	Income taxes due to customers				19			21
	Other				28			9
		Total deferred tax assets			121			100
Deferred Tax Liabilities
	Plant - net				585			526
	Regulatory assets				83			86
	Accrued pension costs				24			27
	Other				8			9
		Total deferred tax liabilities			700			648
Net deferred tax liability				$	579		$	548
LG&E expects to have adequate levels of taxable income to realize its recorded deferred income tax assets.
At December 31, 2013, LG&E had $10 million of federal net operating loss carryforwards that expire in 2032 and $22 million of state net operating loss carryforwards that expire in 2030.
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:
					2013			2012			2011
Income Tax Expense (Benefit)
	Current - Federal				$	52		$	-2		$	12
	Current - State					16			3			8
			Total Current Expense (Benefit)			68			1			20
	Deferred - Federal					33			65			52
	Deferred - State					-2			6			2
			Total Deferred Expense, excluding benefits of operating loss carryforwards			31			71			54
	Investment tax credit, net - Federal					-2			-3			-3
	Tax benefit of operating loss carryforwards
		Deferred - Federal				-3
			Total Tax Benefit of Operating Loss Carryforwards			-3
	Total income tax expense				$	94		$	69		$	71
	Total income tax expense - Federal				$	80		$	60		$	61
	Total income tax expense - State					14			9			10
			Total income tax expense		$	94		$	69		$	71
					2013			2012			2011
Reconciliation of Income Taxes
	Federal income tax on Income Before Income Taxes at
		statutory tax rate - 35%			$	90		$	67		$	68
Increase (decrease) due to:
	State income taxes, net of federal income tax benefit					10			5			7
	Amortization of investment tax credit					-2			-3			-3
	Other					-4						-1
			Total increase (decrease)			4			2			3
Total income tax expense					$	94		$	69		$	71
Effective income tax rate						36.60%			35.90%			36.40%
					2013			2012			2011
Taxes, other than income
	Property and other				$	24		$	23		$	18
			Total		$	24		$	23		$	18
(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 deferred income tax assets and liabilities were as follows:
				2013			2012
Deferred Tax Assets
	Regulatory liabilities			$	47		$	45
	Deferred investment tax credits				38			38
	Net operating loss carryforward				23			20
	Income taxes due to customers				4			5
	Accrued pension costs							-5
	Other				8			7
		Total deferred tax assets			120			110
Deferred Tax Liabilities
	Plant - net				721			623
	Regulatory assets				50			65
	Other				4			5
		Total deferred tax liabilities			775			693
Net deferred tax liability				$	655		$	583
KU expects to have adequate levels of taxable income to realize its recorded deferred income tax assets.
At December 31, 2013, KU had $65 million of federal net operating loss carryforwards that expire in 2032.
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:
					2013			2012			2011
Income Tax Expense (Benefit)
	Current - Federal				$	51		$	-20		$	-8
	Current - State					12			-1			4
			Total Current Expense (Benefit)			63			-21			-4
	Deferred - Federal					66			111			101
	Deferred - State					8			11			10
			Total Deferred Expense, excluding benefits of operating loss carryforwards			74			122			111
	Investment tax credit, net - Federal					-2			-3			-3
	Tax benefit of operating loss carryforwards
		Deferred - Federal				-3			-20
			Total Tax Benefit of Operating Loss Carryforwards			-3			-20
	Total income tax expense (a)				$	132		$	78		$	104
	Total income tax expense - Federal				$	112		$	68		$	90
	Total income tax expense - State					20			10			14
			Total income tax expense (a)		$	132		$	78		$	104
(a)       Excludes deferred federal and state tax (benefit) recorded to OCI of less than $1 million in 2013 and $1 million in 2012.
					2013			2012			2011
Reconciliation of Income Taxes
	Federal income tax on Income Before Income Taxes at
		statutory tax rate - 35%			$	126		$	75		$	99
Increase (decrease) due to:
	State income taxes, net of federal income tax benefit					14			6			9
	Amortization of investment tax credit					-2			-3			-3
	Other					-6						-1
			Total increase (decrease)			6			3			5
Total income tax expense					$	132		$	78		$	104
Effective income tax rate						36.70%			36.30%			36.90%
					2013			2012			2011
Taxes, other than income
	Property and other				$	24		$	23		$	19
			Total		$	24		$	23		$	19
Unrecognized Tax Benefits (All Registrants)
Changes to unrecognized tax benefits were as follows:
			2013			2012
PPL
	Beginning of period		$	92		$	145
	Additions based on tax positions of prior years			3			15
	Reductions based on tax positions of prior years			-32			-61
	Additions based on tax positions related to the current year						7
	Reductions based on tax positions related to the current year						-3
	Settlements			-30			-2
	Lapse of applicable statute of limitation			-11			-9
	End of period		$	22		$	92
PPL Energy Supply
	Beginning of period		$	30		$	28
	Additions based on tax positions of prior years						4
	Reductions based on tax positions of prior years			-15			-2
	End of period		$	15		$	30
PPL Electric
	Beginning of period		$	26		$	73
	Reductions based on tax positions of prior years			-17			-43
	Additions based on tax positions related to the current year						5
	Lapse of applicable statute of limitation			-9			-9
	End of period		$			$	26
LKE's, LG&E's and KU's unrecognized tax benefits and changes in those unrecognized tax benefits are insignificant at December 31, 2013 and December 31, 2012.
At December 31, 2013, it was reasonably possible that during the next 12 months the total amount of unrecognized tax benefits could increase or decrease by the following amounts. For PPL Electric, LKE, LG&E and KU, no significant changes in unrecognized tax benefits are projected over the next 12 months.
		Increase			Decrease
PPL		$			$	22
PPL Energy Supply						15
These potential changes could result from subsequent recognition, derecognition and/or changes in the measurement of uncertain tax positions related to the creditability of foreign taxes, the timing and utilization of foreign tax credits and the related impact on alternative minimum tax and other credits, the timing and/or valuation of certain deductions, intercompany transactions and unitary filing groups. The events that could cause these changes are direct settlements with taxing authorities, litigation, legal or administrative guidance by relevant taxing authorities and the lapse of an applicable statute of limitation.
At December 31, the total unrecognized tax benefits and related indirect effects that, if recognized, would decrease the effective tax rate were as follows. The amounts for LKE, LG&E and KU were insignificant.
		2013			2012
PPL		$	21		$	38
PPL Energy Supply			14			13
PPL Electric						3
At December 31, the following receivable (payable) balances were recorded for interest related to tax positions. The amounts for LKE, LG&E and KU were insignificant.
		2013			2012
PPL		$	15		$	-16
PPL Energy Supply			15			17
PPL Electric			3			1
The following interest expense (benefit) was recognized in income taxes. The amounts for LKE, LG&E and KU were insignificant.
		2013			2012			2011
PPL		$	-30		$	-4		$	27
PPL Energy Supply			5			-4			6
PPL Electric			-7			-4			-5
PPL or its subsidiaries file tax returns in five major tax jurisdictions. The income tax provisions for PPL Energy Supply, 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 subsidiary filed a separate consolidated return. Based on this tax sharing agreement, PPL Energy Supply or its subsidiaries indirectly or directly file tax returns in three major tax jurisdictions, PPL Electric or its subsidiaries indirectly or directly file tax returns in two major tax jurisdictions, and LKE, LG&E and KU or their subsidiaries indirectly or directly file tax returns in two major tax jurisdictions. With few exceptions, at December 31, 2013, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows:
				PPL
		PPL		Energy Supply		PPL Electric		LKE		LG&E		KU
U.S. (federal) (a)		1997 and prior		1997 and prior		1997 and prior		10/31/2010 and prior		10/31/2010 and prior		10/31/2010 and prior
Pennsylvania (state)		2009 and prior		2009 and prior		2008 and prior
Kentucky (state)		2008 and prior						2010 and prior		2010 and prior		2010 and prior
Montana (state)		2009 and prior		2009 and prior
U.K. (foreign)		2011 and prior
(a)        For LKE, LG&E, and KU, the ten month period ending October 31, 2010 remains open under the standard three year statute of limitations; however, the IRS has completed its audit of these periods under the Compliance Assurance Process, effectively closing them to audit adjustments. No issues remain outstanding.
Other (PPL, PPL Energy Supply and PPL Electric)
PPL changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year for Pennsylvania operations. PPL made the same change for its Montana operations for the 2009 tax year. In 2011, the IRS issued guidance on repair expenditures related to network assets providing a safe harbor method of determining whether the repair expenditures can be currently deducted for tax purposes. On April 30, 2013, the IRS issued Revenue Procedure 2013-24 providing guidance to taxpayers to determine whether expenditures to maintain, replace or improve steam or electric generation property must be capitalized for tax purposes. PPL believes that this guidance will not have a material impact on PPL's current treatment of such expenditures. The IRS may assert, and ultimately conclude, that PPL's deduction for generation-related expenditures should be less than the amount determined by PPL. PPL believes that it has established adequate reserves for this contingency.

Utility_Rate_Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2013
Utility Rate Regulation [Line Items]	'
Utility Rate Regulation	'
	6. Utility Rate Regulation
	Regulatory Assets and Liabilities
	(All Registrants except PPL Energy Supply)
	As discussed in Note 1 and summarized below, 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 KPSC 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 calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets.
	As a result of purchase accounting requirements, certain fair value amounts related to contracts that had favorable or unfavorable terms relative to market were recorded on the Balance Sheets with an offsetting regulatory asset or liability. LG&E and KU recover in customer rates the cost of 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 and 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. Therefore, 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 rate 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 development of municipal rates. Therefore, no return is earned on the related assets.
	(PPL and PPL Electric)
	PPL Electric's distribution base rates are calculated based on a return on rate base (net utility plant plus a cash 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 plant 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 except PPL Energy Supply)
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
	Demand side management			8			1			3			1			5
Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
Noncurrent Regulatory Assets:
	Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
	Storm costs			94			109			51			59			43			50
	Unamortized loss on debt			28			31			18			20			10			11
	Interest rate swaps			44			67			44			67
	AROs			44			26			21			15			23			11
	Other			12			29			5			7			7			22
Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
Current Regulatory Liabilities:
		Environmental cost recovery					$	4											$	4
		Gas supply clause		$	3			4		$	3		$	4
		Fuel adjustment clause			4			1								$	4			1
		Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition 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."
(All Registrants except PPL Energy Supply)
Defined Benefit Plans
Defined benefit plan regulatory assets and liabilities represent the portion of unrecognized transition obligation, prior service cost and net actuarial losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is re-measured. Of the regulatory asset and liability balances recorded, costs of $28 million for PPL, $9 million for PPL Electric, $19 million for LKE, $13 million for LG&E and $6 million for KU are expected to be amortized into net periodic defined benefit costs in 2014.
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 and amortize such costs for regulatory accounting and reporting purposes. Once such authority is granted, PPL Electric, LG&E and KU can request recovery of those expenses in a base rate case.
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. Such costs are being amortized through 2040 for PPL, LKE and KU, and through 2035 for LG&E.
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. See Note 1 for additional information.
PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the deferral of 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 permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply (energy and capacity and ancillary services), as well as administration 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 service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year.
Transmission Formula Rate
PPL Electric's transmission revenues are billed in accordance with a FERC-approved open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is based on prior year expenditures and forecasted current calendar year transmission plant additions. An adjustment to the prior year expenditures is recorded as a regulatory asset or liability.
Universal Service Rider (USR)
PPL Electric's distribution rates permit recovery of applicable costs associated with the universal service programs provided to PPL Electric's residential customers. Universal service programs include low-income programs, such as OnTrack and Winter Relief Assistance Program (WRAP). OnTrack is a special payment program for low-income households within the federal poverty level that have difficulty paying their electric bills. This program is funded by residential customers and administered by community-based organizations. Customers who participate in OnTrack receive assistance in the form of reduced payment arrangements, protection against termination of electric service and referrals to other community programs and services. The WRAP program reduces electric bills and improves living comfort for low-income customers by providing services such as weatherization measures and energy education services. The USR is applied to distribution charges for each customer who receives distribution service under PPL Electric's residential service rate schedules. The USR contains a reconciliation mechanism whereby any over- or under-recovery from the current year is refunded to or recovered from residential customers through the adjustment factor determined for the subsequent year.
Storm Damage Expense
In accordance with the PUC's December 2012 final rate case order, PPL Electric proposed the establishment of a Storm Damage Expense Rider with the PUC. The matter remains open before the PUC. Based on 2013 actual storm experience, PPL Electric established a $14 million regulatory liability at December 31, 2013 for revenues collected from customers to cover storm costs in excess of actual storm costs incurred.
Taxes Recoverable through Future Rates
Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred.
Act 129 Compliance Rider
In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, Phase I of PPL Electric's energy efficiency and conservation plan was 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 beginning 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 Activities" for additional information on Act 129.
(PPL, LKE, LG&E and KU)
Environmental Cost Recovery
Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements which apply to coal combustion wastes and by-products from coal-fired 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. 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. As a result of the settlement agreement in the 2012 rate case, beginning in 2013, LG&E and KU will receive a 10.25% return on equity for all ECR projects included in the 2009 and 2011 compliance plans. In 2012 and 2011, LG&E and KU were authorized to receive a 10.63% return on equity for projects associated with the 2009 compliance plan and a 10.10% return on equity for projects associated with the 2011 compliance plan.
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 represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered within 18 months.
Fuel Adjustment Clauses
LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires public hearings at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months.
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 which 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 allows for the recovery of DSM revenues from lost sales associated with the DSM programs. Additionally, LG&E and KU earn an approved return on equity for capital expenditures associated with the residential and commercial load management/demand conservation programs. 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)
In November 2012 and April 2013, LG&E and KU entered into forward-starting interest rate swaps with PPL that hedged the interest payments on new debt that was expected to be issued in 2013. In September 2013, these hedges were terminated and LG&E and KU entered into new forward-starting interest rate swaps with PPL, effectively extending the start date of the prior hedges from September 2013 to December 2013. All of these swaps had terms identical to forward-starting swaps entered into by PPL with third parties. New debt totaling $500 million was issued in November 2013 (LG&E and KU each issued $250 million) and the hedges issued in September were terminated in November 2013. Net cash settlements of $86 million (LG&E and KU each received $43 million) were received on the swaps that were terminated in September and November, which are included in "Cash Flows from Operating Activities" on the Statements of Cash Flows. Net realized gains on these swaps will be returned through regulated rates. As such, the net settlements were reclassified from AOCI to regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the newly issued debt. For the year ended December 31, 2013, there was no hedge ineffectiveness recorded for the interest rate derivatives. See Note 19 for additional information related to the forward-starting interest rate swaps.
(PPL, LKE and LG&E)
In addition to the hedges terminated as a result of the debt issuance, realized amounts associated with LG&E's interest rate swaps, including a terminated swap contract from 2008, are recoverable through rates based on an order from the KPSC, LG&E's unrealized losses 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, as approved by the KPSC.
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, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.
Gas Line Tracker
In the 2012 rate case order, the KPSC approved the GLT rate recovery mechanism. The GLT authorizes LG&E to recover its incremental operating expenses and depreciation, and to earn a 10.25% return on equity for capital associated with the five year gas service riser and leak mitigation program. As part of this 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 adjustment filing to the KPSC to amend rates charged for the differences between the actual costs and actual GLT charges for the preceding year.
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 unfavorable terms relative to current market prices and offsets to regulatory liabilities for those contracts with favorable terms relative to current market prices. These 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 are 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 Associated with Net Deferred Tax Assets
LG&E's and KU's regulatory 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 offsetting deferred tax assets are recognized. For general-purpose financial reporting, these regulatory liabilities and the deferred tax assets are not offset; rather, each is displayed separately.
Regulatory Matters
U.K. Activities (PPL)
Ofgem Review of Line Loss Calculation
Ofgem is currently consulting on the methodology to be used by all network operators to calculate the final line loss incentives and penalties for the DPCR4.  WPD had a $74 million liability recorded at December 31, 2013, compared with $94 million at December 31, 2012. In the fourth quarter of 2012, based on applying the preferred methodology indicated by Ofgem in a consultation issued in November 2012, the liability was reduced by $79 million with a credit recorded in "Utility" revenue on the Statement of Income. In July 2013, Ofgem issued a decision paper on the process to follow for closing out the line loss calculation. Subsequent to the July 2013 decision paper, WPD received additional information from Ofgem. As a result, during 2013, WPD recorded increases of $45 million to the liability with reductions to "Utility" revenue on the Statement of Income. Other changes to the liability in 2013 included reductions of $66 million resulting from refunds being included in tariffs and foreign exchange movements. The potential loss exposure is estimated to be in the range of $74 million to $213 million as of December 31, 2013. PPL cannot predict the outcome of this matter.
European Market Infrastructure Regulation
Regulation No. 648/2012 of the European Parliament and of the Council, commonly referred to as the European Market Infrastructure Regulation (EMIR), entered into force on August 16, 2012 and the European Commission adopted most of the Regulatory Technical Standards without modification in December 2012. The EMIR establishes certain transaction clearing and other recordkeeping requirements for parties to over-the-counter derivatives transactions. Included in the derivative transactions that are subject to EMIR are certain interest rate and currency derivative contracts utilized by WPD. Although the EMIR will potentially impose significant additional recordkeeping requirements on WPD, the effect of the EMIR is not currently expected to have a significant adverse impact on WPD's financial condition or results of operation.
Kentucky Activities
(PPL, LKE, LG&E and KU)
Rate Case Proceedings
In December 2012, the KPSC approved a rate case settlement agreement providing for increases in annual base electricity rates of $34 million for LG&E and $51 million for KU and an increase in annual base gas rates of $15 million for LG&E and authorizes a 10.25% return on equity. The approved rates became effective January 1, 2013.
(PPL, LKE and LG&E)
CPCN Filings
In January 2014, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to build a NGCC generating unit at KU's Green River generating site and a solar generating facility at the E. W. Brown generating site.
Storm Costs
In August 2011, a strong storm hit LG&E's service area causing significant damage and widespread outages for approximately 139,000 customers. LG&E filed an application with the KPSC in September 2011, requesting approval of a regulatory asset recorded to defer, for future recovery, $8 million in incremental operation and maintenance expenses related to the storm restoration. An order was received in December 2011 granting the request. On December 20, 2012, the KPSC, in the approval of the unanimous rate case settlement agreement, authorized regulatory asset recovery effective January 1, 2013, over a five year period.
Pennsylvania Activities (PPL and PPL Electric)
Rate Case Proceeding
In December 2012, the PUC approved a total distribution revenue increase of about $71 million for PPL Electric, including a 10.4% allowed return on equity. The approved rates became effective January 1, 2013.
Storm Damage Expense Rider
In its December 28, 2012 final rate case order, the PUC directed PPL Electric to file a proposed Storm Damage Expense Rider (SDER).  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 included in rates effective January 1, 2014.  In April 2013, parties filed comments opposing the SDER.  PPL Electric and several other parties filed reply comments in May 2013.  In November 2013, the PUC suspended the effective date of the rider to February 28, 2014 and requested additional comments and reply comments on PPL Electric's proposal.  Comments and reply comments have been filed. On February 10, 2014, PPL Electric agreed to an additional suspension of the effective date of the rider to May 1, 2014. This matter remains pending before the PUC.
Act 129
Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet specified goals for reduction in customer electricity usage and peak demand by specified dates. EDCs not meeting the requirements of Act 129 are subject to significant penalties.
Under Act 129, EDCs must file an energy efficiency and conservation plan (EE&C Plan) with the PUC and contract with conservation service providers to implement all or a portion of the EE&C Plan. EDCs are able to recover the costs (capped at 2.0% of the EDC's 2006 revenue) of implementing their EE&C Plans. In October 2009, the PUC approved PPL Electric's Phase 1 EE&C Plan ending May 31, 2013.
Act 129 required EDCs to reduce overall electricity consumption by 1.0% by May 2011 and by 3.0% by May 2013, and reduce peak demand by 4.5% by May 2013. The overall consumption reduction is measured against PUC-forecasted consumption for the twelve months ended May 31, 2010. The peak demand reduction was required to occur for the 100 hours of highest demand, which is determined by actual demand reduction during the June 2012 through September 2012 period. PPL Electric believes it has met the May 2011 and May 2013 overall electricity consumption requirements, and the peak demand reduction requirement based on the results of its November 15, 2013 Act 129 Final Annual Report. PPL Electric does not expect the PUC to formally determine compliance for either the 2011 or 2013 requirements until after the first quarter of 2014.
Act 129 requires the PUC to evaluate the costs and benefits of the EE&C program by November 30, 2013 and adopt additional reductions if the benefits of the program exceed the costs. In August 2012, after receiving input from stakeholders, the PUC issued a Final Implementation Order establishing a three-year Phase II program, ending May 31, 2016, with individual consumption reduction targets for each EDC. PPL Electric's Phase II reduction target is 2.1% of the total energy consumption forecasted by the PUC for the twelve months ended May 31, 2010. The PUC did not establish demand reduction targets for the Phase II program. PPL Electric filed its Phase II EE&C Plan with the PUC on November 15, 2012 and, in March 2013, the PUC approved PPL Electric's Phase II EE&C Plan with minor modifications. PPL Electric filed a Revised Phase II EE&C Plan on May 13, 2013 pursuant to the PUC's March Order. On July 11, 2013, the PUC issued an Order approving PPL Electric's Revised Phase II EE&C Plan. PPL Electric began its Phase II Plan implementation on June 1, 2013. In November 2013, PPL Electric filed 40 modifications to its Phase II Plan which contains programs designed to meet PPL Electric's target of reducing total energy consumption by 2.1%. Parties have filed comments and reply comments on PPL Electric's proposal.
Act 129 also requires Default Service Providers (DSP) to provide electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan through auctions, requests for proposal and bilateral contracts at the sole discretion of the DSP. Act 129 requires a mix of spot market purchases, short-term contracts and long-term contracts (4 to 20 years), with long-term contracts limited to 25% of load unless otherwise approved by the PUC. A DSP is able to recover the costs associated with its default service procurement plan.
The PUC approved PPL Electric's DSP procurement plan for the period January 1, 2011 through May 31, 2013, and PPL Electric has concluded all competitive solicitations to procure power for its PLR obligations under that plan.
The PUC directed all EDCs to file default service procurement plans for the period June 1, 2013 through May 31, 2015. PPL Electric filed its plan in May 2012. In that plan, PPL Electric proposed a process to obtain supply for its default service customers and a number of initiatives designed to encourage more customers to purchase electricity from the competitive retail market. In January 2013, the PUC approved PPL Electric's plan with modifications. PPL Electric filed revised retail competition initiatives and a revised plan consistent with the PUC's January order, and in May 2013, the PUC approved that filing with minor changes. PPL Electric began implementing its revised plan on June 1, 2013. PPL Electric anticipates filing its default service procurement plan for the period beginning June 1, 2015 in the second quarter of 2014.
Smart Meter Rider
Act 129 also requires installation of smart meters for new construction, upon the request of consumers and at their cost, or on a depreciation schedule not exceeding 15 years. Under Act 129, EDCs are able to recover the costs of providing smart metering technology. All of PPL Electric's metered customers currently have advanced meters installed at their service locations capable of many of the functions required under Act 129. PPL Electric continues to conduct pilot projects to evaluate additional applications of its current advanced metering technology pursuant to the requirements of Act 129. PPL Electric recovers the cost of its pilot projects through a cost recovery mechanism, the Smart Meter Rider (SMR). In August 2013, PPL Electric filed with the PUC an annual report describing the actions it was taking under its Smart Meter Plan during 2013 and its planned actions for 2014. PPL Electric also submitted revised SMR charges that became effective January 1, 2014. PPL Electric will submit its final Smart Meter Plan by June 30, 2014.
PUC Investigation of Retail Electricity Market
In April 2011, the PUC opened an investigation of Pennsylvania's retail electricity market to be conducted in two phases. Phase one addressed the status of the existing retail market and explored potential changes. Questions issued by the PUC for phase one of the investigation focused primarily on default service issues. Phase two was initiated in July 2011 to develop specific proposals for changes to the retail market and default service model. From December 2011 through the end of 2012, the PUC issued several orders and other pronouncements related to the investigation. A final implementation order was issued in February 2013, and the PUC created several working groups to address continuing competitive issues. Although the final implementation order contains provisions that will require numerous modifications to PPL Electric's current default service model for retail customers, those modifications are not expected to have a material adverse effect on PPL Electric's results of operations.
Distribution System Improvement Charge
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 begins a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging distribution assets. In August 2012, the PUC issued a Final Implementation Order adopting procedures, guidelines and a model tariff for the implementation of Act 11. Act 11 requires utilities to file an LTIIP as a prerequisite to filing for recovery through the DSIC. The LTIIP is mandated to be a five- to ten-year plan describing projects eligible for inclusion in the DSIC.
In September 2012, PPL Electric filed its LTIIP describing projects eligible for inclusion in the DSIC. The PUC approved the LTIIP on January 10, 2013 and, on January 15, 2013, PPL Electric filed a petition requesting permission to establish a DSIC. Several parties filed responses to PPL Electric's petition. 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 refund 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. The case remains pending before the PUC.
Storm Costs
During 2012, PPL Electric experienced several PUC-reportable storms, including Hurricane Sandy, resulting in total restoration costs of $81 million, of which $61 million were initially recorded in “Other operation and maintenance” on the Statement of Income.  In particular, in late October 2012, PPL Electric experienced widespread significant damage to its distribution network from Hurricane Sandy resulting in total restoration costs of $66 million, of which $50 million were initially recorded in “Other operation and maintenance” on the Statement of Income. Although PPL Electric had storm insurance coverage, the costs incurred from Hurricane Sandy exceeded the policy limits. Probable insurance recoveries recorded during 2012 were $18.25 million, of which $14 million were included in "Other operation and maintenance" on the Statement of Income. At December 31, 2013 and 2012, respectively, $29 million and $28 million was included on the Balance Sheets as a regulatory asset. In February 2013, PPL Electric received an order from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Sandy. See “Storm Damage Expense Rider” above for information regarding PPL Electric's plan to file a proposed Storm Damage Expense Rider with the PUC.
PPL Electric experienced several PUC-reportable storms during 2011 including Hurricane Irene and a late October snow storm. Total restoration costs were $84 million, of which $54 million were initially recorded in "Other operation and maintenance" on the Statement of Income. Although PPL Electric had storm insurance coverage with a PPL affiliate, the costs associated with the unusually high number of PUC-reportable storms exceeded policy limits. Probable insurance recoveries recorded during 2011 were $26.5 million, of which $16 million were included in "Other operation and maintenance" on the Statements of Income. In December 2011, PPL Electric received orders from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Irene and a late October 2011 snowstorm. PPL Electric recorded a regulatory asset of $25 million in December 2011 (offset to "Other operation and maintenance" on the Statement of Income). The PUC granted PPL Electric's recovery of the 2011 storm costs in its final order in the 2012 rate case. Recovery began in January 2013 and will continue over a five-year period.
Federal Matters
FERC Formula Rates (PPL and PPL Electric)
Transmission rates are regulated by the FERC. PPL Electric's transmission revenues are billed in accordance with a FERC-approved PJM open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is calculated, in part, based on financial results as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts.
PPL Electric initiated its formula rate 2012, 2011 and 2010 Annual Updates. Each update was subsequently challenged by a group of municipal customers, which challenges have been opposed by PPL Electric. In August 2011, the FERC issued an order substantially rejecting the 2010 formal challenge and the municipal customers filed a request for rehearing of that order. In September 2012, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues raised in the 2010 and 2011 formal challenges. Settlement conferences were held in late 2012 and early 2013. In February 2013, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues in the 2012 formal challenge and consolidated that challenge with the 2010 and 2011 challenges. PPL Electric filed a request for rehearing of the February order which remains pending before the FERC. PPL Electric and the group of municipal customers have exchanged confidential settlement proposals and PPL Electric anticipates that there will be additional settlement conferences held in 2014. PPL and PPL Electric cannot predict the outcome of the foregoing proceedings, which remain pending before the FERC.
In May 2013, PPL Electric filed its 2013 Annual Update with rates proposed to become effective on June 1, 2013. The rates became effective as proposed, and no party has filed a challenge to the 2013 updated rates.
FERC Formula Rates (KU)
In May 2013, KU submitted to the FERC the annual adjustments to the formula rate, which incorporated certain proposed increases.  These rates became effective as of July 1, 2013.
In September 2013, KU filed an application with the FERC to adjust the formula rate under which KU provides wholesale requirements power sales to 12 municipal customers.  Among other changes, the application requests an amended formula whereby KU would charge cost-based rates with a subsequent true-up to actual costs, replacing the current formula which does not include such a true-up.  KU's application proposed an authorized return on equity of 10.7%.  Subject to regulatory approval, the new formula rate may become effective during the second quarter of 2014.
PPL Electric Utilities Corp [Member]	'
Utility Rate Regulation [Line Items]	'
Utility Rate Regulation	'
	6. Utility Rate Regulation
	Regulatory Assets and Liabilities
	(All Registrants except PPL Energy Supply)
	As discussed in Note 1 and summarized below, 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 KPSC 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 calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets.
	As a result of purchase accounting requirements, certain fair value amounts related to contracts that had favorable or unfavorable terms relative to market were recorded on the Balance Sheets with an offsetting regulatory asset or liability. LG&E and KU recover in customer rates the cost of 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 and 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. Therefore, 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 rate 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 development of municipal rates. Therefore, no return is earned on the related assets.
	(PPL and PPL Electric)
	PPL Electric's distribution base rates are calculated based on a return on rate base (net utility plant plus a cash 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 plant 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 except PPL Energy Supply)
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
	Demand side management			8			1			3			1			5
Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
Noncurrent Regulatory Assets:
	Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
	Storm costs			94			109			51			59			43			50
	Unamortized loss on debt			28			31			18			20			10			11
	Interest rate swaps			44			67			44			67
	AROs			44			26			21			15			23			11
	Other			12			29			5			7			7			22
Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
Current Regulatory Liabilities:
		Environmental cost recovery					$	4											$	4
		Gas supply clause		$	3			4		$	3		$	4
		Fuel adjustment clause			4			1								$	4			1
		Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition 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."
(All Registrants except PPL Energy Supply)
Defined Benefit Plans
Defined benefit plan regulatory assets and liabilities represent the portion of unrecognized transition obligation, prior service cost and net actuarial losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is re-measured. Of the regulatory asset and liability balances recorded, costs of $28 million for PPL, $9 million for PPL Electric, $19 million for LKE, $13 million for LG&E and $6 million for KU are expected to be amortized into net periodic defined benefit costs in 2014.
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 and amortize such costs for regulatory accounting and reporting purposes. Once such authority is granted, PPL Electric, LG&E and KU can request recovery of those expenses in a base rate case.
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. Such costs are being amortized through 2040 for PPL, LKE and KU, and through 2035 for LG&E.
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. See Note 1 for additional information.
PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the deferral of 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 permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply (energy and capacity and ancillary services), as well as administration 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 service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year.
Transmission Formula Rate
PPL Electric's transmission revenues are billed in accordance with a FERC-approved open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is based on prior year expenditures and forecasted current calendar year transmission plant additions. An adjustment to the prior year expenditures is recorded as a regulatory asset or liability.
Universal Service Rider (USR)
PPL Electric's distribution rates permit recovery of applicable costs associated with the universal service programs provided to PPL Electric's residential customers. Universal service programs include low-income programs, such as OnTrack and Winter Relief Assistance Program (WRAP). OnTrack is a special payment program for low-income households within the federal poverty level that have difficulty paying their electric bills. This program is funded by residential customers and administered by community-based organizations. Customers who participate in OnTrack receive assistance in the form of reduced payment arrangements, protection against termination of electric service and referrals to other community programs and services. The WRAP program reduces electric bills and improves living comfort for low-income customers by providing services such as weatherization measures and energy education services. The USR is applied to distribution charges for each customer who receives distribution service under PPL Electric's residential service rate schedules. The USR contains a reconciliation mechanism whereby any over- or under-recovery from the current year is refunded to or recovered from residential customers through the adjustment factor determined for the subsequent year.
Storm Damage Expense
In accordance with the PUC's December 2012 final rate case order, PPL Electric proposed the establishment of a Storm Damage Expense Rider with the PUC. The matter remains open before the PUC. Based on 2013 actual storm experience, PPL Electric established a $14 million regulatory liability at December 31, 2013 for revenues collected from customers to cover storm costs in excess of actual storm costs incurred.
Taxes Recoverable through Future Rates
Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred.
Act 129 Compliance Rider
In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, Phase I of PPL Electric's energy efficiency and conservation plan was 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 beginning 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 Activities" for additional information on Act 129.
(PPL, LKE, LG&E and KU)
Environmental Cost Recovery
Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements which apply to coal combustion wastes and by-products from coal-fired 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. 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. As a result of the settlement agreement in the 2012 rate case, beginning in 2013, LG&E and KU will receive a 10.25% return on equity for all ECR projects included in the 2009 and 2011 compliance plans. In 2012 and 2011, LG&E and KU were authorized to receive a 10.63% return on equity for projects associated with the 2009 compliance plan and a 10.10% return on equity for projects associated with the 2011 compliance plan.
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 represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered within 18 months.
Fuel Adjustment Clauses
LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires public hearings at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months.
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 which 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 allows for the recovery of DSM revenues from lost sales associated with the DSM programs. Additionally, LG&E and KU earn an approved return on equity for capital expenditures associated with the residential and commercial load management/demand conservation programs. 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)
In November 2012 and April 2013, LG&E and KU entered into forward-starting interest rate swaps with PPL that hedged the interest payments on new debt that was expected to be issued in 2013. In September 2013, these hedges were terminated and LG&E and KU entered into new forward-starting interest rate swaps with PPL, effectively extending the start date of the prior hedges from September 2013 to December 2013. All of these swaps had terms identical to forward-starting swaps entered into by PPL with third parties. New debt totaling $500 million was issued in November 2013 (LG&E and KU each issued $250 million) and the hedges issued in September were terminated in November 2013. Net cash settlements of $86 million (LG&E and KU each received $43 million) were received on the swaps that were terminated in September and November, which are included in "Cash Flows from Operating Activities" on the Statements of Cash Flows. Net realized gains on these swaps will be returned through regulated rates. As such, the net settlements were reclassified from AOCI to regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the newly issued debt. For the year ended December 31, 2013, there was no hedge ineffectiveness recorded for the interest rate derivatives. See Note 19 for additional information related to the forward-starting interest rate swaps.
(PPL, LKE and LG&E)
In addition to the hedges terminated as a result of the debt issuance, realized amounts associated with LG&E's interest rate swaps, including a terminated swap contract from 2008, are recoverable through rates based on an order from the KPSC, LG&E's unrealized losses 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, as approved by the KPSC.
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, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.
Gas Line Tracker
In the 2012 rate case order, the KPSC approved the GLT rate recovery mechanism. The GLT authorizes LG&E to recover its incremental operating expenses and depreciation, and to earn a 10.25% return on equity for capital associated with the five year gas service riser and leak mitigation program. As part of this 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 adjustment filing to the KPSC to amend rates charged for the differences between the actual costs and actual GLT charges for the preceding year.
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 unfavorable terms relative to current market prices and offsets to regulatory liabilities for those contracts with favorable terms relative to current market prices. These 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 are 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 Associated with Net Deferred Tax Assets
LG&E's and KU's regulatory 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 offsetting deferred tax assets are recognized. For general-purpose financial reporting, these regulatory liabilities and the deferred tax assets are not offset; rather, each is displayed separately.
Regulatory Matters
U.K. Activities (PPL)
Ofgem Review of Line Loss Calculation
Ofgem is currently consulting on the methodology to be used by all network operators to calculate the final line loss incentives and penalties for the DPCR4.  WPD had a $74 million liability recorded at December 31, 2013, compared with $94 million at December 31, 2012. In the fourth quarter of 2012, based on applying the preferred methodology indicated by Ofgem in a consultation issued in November 2012, the liability was reduced by $79 million with a credit recorded in "Utility" revenue on the Statement of Income. In July 2013, Ofgem issued a decision paper on the process to follow for closing out the line loss calculation. Subsequent to the July 2013 decision paper, WPD received additional information from Ofgem. As a result, during 2013, WPD recorded increases of $45 million to the liability with reductions to "Utility" revenue on the Statement of Income. Other changes to the liability in 2013 included reductions of $66 million resulting from refunds being included in tariffs and foreign exchange movements. The potential loss exposure is estimated to be in the range of $74 million to $213 million as of December 31, 2013. PPL cannot predict the outcome of this matter.
European Market Infrastructure Regulation
Regulation No. 648/2012 of the European Parliament and of the Council, commonly referred to as the European Market Infrastructure Regulation (EMIR), entered into force on August 16, 2012 and the European Commission adopted most of the Regulatory Technical Standards without modification in December 2012. The EMIR establishes certain transaction clearing and other recordkeeping requirements for parties to over-the-counter derivatives transactions. Included in the derivative transactions that are subject to EMIR are certain interest rate and currency derivative contracts utilized by WPD. Although the EMIR will potentially impose significant additional recordkeeping requirements on WPD, the effect of the EMIR is not currently expected to have a significant adverse impact on WPD's financial condition or results of operation.
Kentucky Activities
(PPL, LKE, LG&E and KU)
Rate Case Proceedings
In December 2012, the KPSC approved a rate case settlement agreement providing for increases in annual base electricity rates of $34 million for LG&E and $51 million for KU and an increase in annual base gas rates of $15 million for LG&E and authorizes a 10.25% return on equity. The approved rates became effective January 1, 2013.
(PPL, LKE and LG&E)
CPCN Filings
In January 2014, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to build a NGCC generating unit at KU's Green River generating site and a solar generating facility at the E. W. Brown generating site.
Storm Costs
In August 2011, a strong storm hit LG&E's service area causing significant damage and widespread outages for approximately 139,000 customers. LG&E filed an application with the KPSC in September 2011, requesting approval of a regulatory asset recorded to defer, for future recovery, $8 million in incremental operation and maintenance expenses related to the storm restoration. An order was received in December 2011 granting the request. On December 20, 2012, the KPSC, in the approval of the unanimous rate case settlement agreement, authorized regulatory asset recovery effective January 1, 2013, over a five year period.
Pennsylvania Activities (PPL and PPL Electric)
Rate Case Proceeding
In December 2012, the PUC approved a total distribution revenue increase of about $71 million for PPL Electric, including a 10.4% allowed return on equity. The approved rates became effective January 1, 2013.
Storm Damage Expense Rider
In its December 28, 2012 final rate case order, the PUC directed PPL Electric to file a proposed Storm Damage Expense Rider (SDER).  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 included in rates effective January 1, 2014.  In April 2013, parties filed comments opposing the SDER.  PPL Electric and several other parties filed reply comments in May 2013.  In November 2013, the PUC suspended the effective date of the rider to February 28, 2014 and requested additional comments and reply comments on PPL Electric's proposal.  Comments and reply comments have been filed. On February 10, 2014, PPL Electric agreed to an additional suspension of the effective date of the rider to May 1, 2014. This matter remains pending before the PUC.
Act 129
Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet specified goals for reduction in customer electricity usage and peak demand by specified dates. EDCs not meeting the requirements of Act 129 are subject to significant penalties.
Under Act 129, EDCs must file an energy efficiency and conservation plan (EE&C Plan) with the PUC and contract with conservation service providers to implement all or a portion of the EE&C Plan. EDCs are able to recover the costs (capped at 2.0% of the EDC's 2006 revenue) of implementing their EE&C Plans. In October 2009, the PUC approved PPL Electric's Phase 1 EE&C Plan ending May 31, 2013.
Act 129 required EDCs to reduce overall electricity consumption by 1.0% by May 2011 and by 3.0% by May 2013, and reduce peak demand by 4.5% by May 2013. The overall consumption reduction is measured against PUC-forecasted consumption for the twelve months ended May 31, 2010. The peak demand reduction was required to occur for the 100 hours of highest demand, which is determined by actual demand reduction during the June 2012 through September 2012 period. PPL Electric believes it has met the May 2011 and May 2013 overall electricity consumption requirements, and the peak demand reduction requirement based on the results of its November 15, 2013 Act 129 Final Annual Report. PPL Electric does not expect the PUC to formally determine compliance for either the 2011 or 2013 requirements until after the first quarter of 2014.
Act 129 requires the PUC to evaluate the costs and benefits of the EE&C program by November 30, 2013 and adopt additional reductions if the benefits of the program exceed the costs. In August 2012, after receiving input from stakeholders, the PUC issued a Final Implementation Order establishing a three-year Phase II program, ending May 31, 2016, with individual consumption reduction targets for each EDC. PPL Electric's Phase II reduction target is 2.1% of the total energy consumption forecasted by the PUC for the twelve months ended May 31, 2010. The PUC did not establish demand reduction targets for the Phase II program. PPL Electric filed its Phase II EE&C Plan with the PUC on November 15, 2012 and, in March 2013, the PUC approved PPL Electric's Phase II EE&C Plan with minor modifications. PPL Electric filed a Revised Phase II EE&C Plan on May 13, 2013 pursuant to the PUC's March Order. On July 11, 2013, the PUC issued an Order approving PPL Electric's Revised Phase II EE&C Plan. PPL Electric began its Phase II Plan implementation on June 1, 2013. In November 2013, PPL Electric filed 40 modifications to its Phase II Plan which contains programs designed to meet PPL Electric's target of reducing total energy consumption by 2.1%. Parties have filed comments and reply comments on PPL Electric's proposal.
Act 129 also requires Default Service Providers (DSP) to provide electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan through auctions, requests for proposal and bilateral contracts at the sole discretion of the DSP. Act 129 requires a mix of spot market purchases, short-term contracts and long-term contracts (4 to 20 years), with long-term contracts limited to 25% of load unless otherwise approved by the PUC. A DSP is able to recover the costs associated with its default service procurement plan.
The PUC approved PPL Electric's DSP procurement plan for the period January 1, 2011 through May 31, 2013, and PPL Electric has concluded all competitive solicitations to procure power for its PLR obligations under that plan.
The PUC directed all EDCs to file default service procurement plans for the period June 1, 2013 through May 31, 2015. PPL Electric filed its plan in May 2012. In that plan, PPL Electric proposed a process to obtain supply for its default service customers and a number of initiatives designed to encourage more customers to purchase electricity from the competitive retail market. In January 2013, the PUC approved PPL Electric's plan with modifications. PPL Electric filed revised retail competition initiatives and a revised plan consistent with the PUC's January order, and in May 2013, the PUC approved that filing with minor changes. PPL Electric began implementing its revised plan on June 1, 2013. PPL Electric anticipates filing its default service procurement plan for the period beginning June 1, 2015 in the second quarter of 2014.
Smart Meter Rider
Act 129 also requires installation of smart meters for new construction, upon the request of consumers and at their cost, or on a depreciation schedule not exceeding 15 years. Under Act 129, EDCs are able to recover the costs of providing smart metering technology. All of PPL Electric's metered customers currently have advanced meters installed at their service locations capable of many of the functions required under Act 129. PPL Electric continues to conduct pilot projects to evaluate additional applications of its current advanced metering technology pursuant to the requirements of Act 129. PPL Electric recovers the cost of its pilot projects through a cost recovery mechanism, the Smart Meter Rider (SMR). In August 2013, PPL Electric filed with the PUC an annual report describing the actions it was taking under its Smart Meter Plan during 2013 and its planned actions for 2014. PPL Electric also submitted revised SMR charges that became effective January 1, 2014. PPL Electric will submit its final Smart Meter Plan by June 30, 2014.
PUC Investigation of Retail Electricity Market
In April 2011, the PUC opened an investigation of Pennsylvania's retail electricity market to be conducted in two phases. Phase one addressed the status of the existing retail market and explored potential changes. Questions issued by the PUC for phase one of the investigation focused primarily on default service issues. Phase two was initiated in July 2011 to develop specific proposals for changes to the retail market and default service model. From December 2011 through the end of 2012, the PUC issued several orders and other pronouncements related to the investigation. A final implementation order was issued in February 2013, and the PUC created several working groups to address continuing competitive issues. Although the final implementation order contains provisions that will require numerous modifications to PPL Electric's current default service model for retail customers, those modifications are not expected to have a material adverse effect on PPL Electric's results of operations.
Distribution System Improvement Charge
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 begins a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging distribution assets. In August 2012, the PUC issued a Final Implementation Order adopting procedures, guidelines and a model tariff for the implementation of Act 11. Act 11 requires utilities to file an LTIIP as a prerequisite to filing for recovery through the DSIC. The LTIIP is mandated to be a five- to ten-year plan describing projects eligible for inclusion in the DSIC.
In September 2012, PPL Electric filed its LTIIP describing projects eligible for inclusion in the DSIC. The PUC approved the LTIIP on January 10, 2013 and, on January 15, 2013, PPL Electric filed a petition requesting permission to establish a DSIC. Several parties filed responses to PPL Electric's petition. 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 refund 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. The case remains pending before the PUC.
Storm Costs
During 2012, PPL Electric experienced several PUC-reportable storms, including Hurricane Sandy, resulting in total restoration costs of $81 million, of which $61 million were initially recorded in “Other operation and maintenance” on the Statement of Income.  In particular, in late October 2012, PPL Electric experienced widespread significant damage to its distribution network from Hurricane Sandy resulting in total restoration costs of $66 million, of which $50 million were initially recorded in “Other operation and maintenance” on the Statement of Income. Although PPL Electric had storm insurance coverage, the costs incurred from Hurricane Sandy exceeded the policy limits. Probable insurance recoveries recorded during 2012 were $18.25 million, of which $14 million were included in "Other operation and maintenance" on the Statement of Income. At December 31, 2013 and 2012, respectively, $29 million and $28 million was included on the Balance Sheets as a regulatory asset. In February 2013, PPL Electric received an order from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Sandy. See “Storm Damage Expense Rider” above for information regarding PPL Electric's plan to file a proposed Storm Damage Expense Rider with the PUC.
PPL Electric experienced several PUC-reportable storms during 2011 including Hurricane Irene and a late October snow storm. Total restoration costs were $84 million, of which $54 million were initially recorded in "Other operation and maintenance" on the Statement of Income. Although PPL Electric had storm insurance coverage with a PPL affiliate, the costs associated with the unusually high number of PUC-reportable storms exceeded policy limits. Probable insurance recoveries recorded during 2011 were $26.5 million, of which $16 million were included in "Other operation and maintenance" on the Statements of Income. In December 2011, PPL Electric received orders from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Irene and a late October 2011 snowstorm. PPL Electric recorded a regulatory asset of $25 million in December 2011 (offset to "Other operation and maintenance" on the Statement of Income). The PUC granted PPL Electric's recovery of the 2011 storm costs in its final order in the 2012 rate case. Recovery began in January 2013 and will continue over a five-year period.
Federal Matters
FERC Formula Rates (PPL and PPL Electric)
Transmission rates are regulated by the FERC. PPL Electric's transmission revenues are billed in accordance with a FERC-approved PJM open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is calculated, in part, based on financial results as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts.
PPL Electric initiated its formula rate 2012, 2011 and 2010 Annual Updates. Each update was subsequently challenged by a group of municipal customers, which challenges have been opposed by PPL Electric. In August 2011, the FERC issued an order substantially rejecting the 2010 formal challenge and the municipal customers filed a request for rehearing of that order. In September 2012, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues raised in the 2010 and 2011 formal challenges. Settlement conferences were held in late 2012 and early 2013. In February 2013, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues in the 2012 formal challenge and consolidated that challenge with the 2010 and 2011 challenges. PPL Electric filed a request for rehearing of the February order which remains pending before the FERC. PPL Electric and the group of municipal customers have exchanged confidential settlement proposals and PPL Electric anticipates that there will be additional settlement conferences held in 2014. PPL and PPL Electric cannot predict the outcome of the foregoing proceedings, which remain pending before the FERC.
In May 2013, PPL Electric filed its 2013 Annual Update with rates proposed to become effective on June 1, 2013. The rates became effective as proposed, and no party has filed a challenge to the 2013 updated rates.
FERC Formula Rates (KU)
In May 2013, KU submitted to the FERC the annual adjustments to the formula rate, which incorporated certain proposed increases.  These rates became effective as of July 1, 2013.
In September 2013, KU filed an application with the FERC to adjust the formula rate under which KU provides wholesale requirements power sales to 12 municipal customers.  Among other changes, the application requests an amended formula whereby KU would charge cost-based rates with a subsequent true-up to actual costs, replacing the current formula which does not include such a true-up.  KU's application proposed an authorized return on equity of 10.7%.  Subject to regulatory approval, the new formula rate may become effective during the second quarter of 2014.
LG And E And KU Energy LLC [Member]	'
Utility Rate Regulation [Line Items]	'
Utility Rate Regulation	'
	6. Utility Rate Regulation
	Regulatory Assets and Liabilities
	(All Registrants except PPL Energy Supply)
	As discussed in Note 1 and summarized below, 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 KPSC 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 calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets.
	As a result of purchase accounting requirements, certain fair value amounts related to contracts that had favorable or unfavorable terms relative to market were recorded on the Balance Sheets with an offsetting regulatory asset or liability. LG&E and KU recover in customer rates the cost of 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 and 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. Therefore, 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 rate 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 development of municipal rates. Therefore, no return is earned on the related assets.
	(PPL and PPL Electric)
	PPL Electric's distribution base rates are calculated based on a return on rate base (net utility plant plus a cash 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 plant 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 except PPL Energy Supply)
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
	Demand side management			8			1			3			1			5
Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
Noncurrent Regulatory Assets:
	Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
	Storm costs			94			109			51			59			43			50
	Unamortized loss on debt			28			31			18			20			10			11
	Interest rate swaps			44			67			44			67
	AROs			44			26			21			15			23			11
	Other			12			29			5			7			7			22
Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
Current Regulatory Liabilities:
		Environmental cost recovery					$	4											$	4
		Gas supply clause		$	3			4		$	3		$	4
		Fuel adjustment clause			4			1								$	4			1
		Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition 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."
(All Registrants except PPL Energy Supply)
Defined Benefit Plans
Defined benefit plan regulatory assets and liabilities represent the portion of unrecognized transition obligation, prior service cost and net actuarial losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is re-measured. Of the regulatory asset and liability balances recorded, costs of $28 million for PPL, $9 million for PPL Electric, $19 million for LKE, $13 million for LG&E and $6 million for KU are expected to be amortized into net periodic defined benefit costs in 2014.
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 and amortize such costs for regulatory accounting and reporting purposes. Once such authority is granted, PPL Electric, LG&E and KU can request recovery of those expenses in a base rate case.
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. Such costs are being amortized through 2040 for PPL, LKE and KU, and through 2035 for LG&E.
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. See Note 1 for additional information.
PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the deferral of 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 permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply (energy and capacity and ancillary services), as well as administration 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 service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year.
Transmission Formula Rate
PPL Electric's transmission revenues are billed in accordance with a FERC-approved open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is based on prior year expenditures and forecasted current calendar year transmission plant additions. An adjustment to the prior year expenditures is recorded as a regulatory asset or liability.
Universal Service Rider (USR)
PPL Electric's distribution rates permit recovery of applicable costs associated with the universal service programs provided to PPL Electric's residential customers. Universal service programs include low-income programs, such as OnTrack and Winter Relief Assistance Program (WRAP). OnTrack is a special payment program for low-income households within the federal poverty level that have difficulty paying their electric bills. This program is funded by residential customers and administered by community-based organizations. Customers who participate in OnTrack receive assistance in the form of reduced payment arrangements, protection against termination of electric service and referrals to other community programs and services. The WRAP program reduces electric bills and improves living comfort for low-income customers by providing services such as weatherization measures and energy education services. The USR is applied to distribution charges for each customer who receives distribution service under PPL Electric's residential service rate schedules. The USR contains a reconciliation mechanism whereby any over- or under-recovery from the current year is refunded to or recovered from residential customers through the adjustment factor determined for the subsequent year.
Storm Damage Expense
In accordance with the PUC's December 2012 final rate case order, PPL Electric proposed the establishment of a Storm Damage Expense Rider with the PUC. The matter remains open before the PUC. Based on 2013 actual storm experience, PPL Electric established a $14 million regulatory liability at December 31, 2013 for revenues collected from customers to cover storm costs in excess of actual storm costs incurred.
Taxes Recoverable through Future Rates
Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred.
Act 129 Compliance Rider
In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, Phase I of PPL Electric's energy efficiency and conservation plan was 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 beginning 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 Activities" for additional information on Act 129.
(PPL, LKE, LG&E and KU)
Environmental Cost Recovery
Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements which apply to coal combustion wastes and by-products from coal-fired 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. 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. As a result of the settlement agreement in the 2012 rate case, beginning in 2013, LG&E and KU will receive a 10.25% return on equity for all ECR projects included in the 2009 and 2011 compliance plans. In 2012 and 2011, LG&E and KU were authorized to receive a 10.63% return on equity for projects associated with the 2009 compliance plan and a 10.10% return on equity for projects associated with the 2011 compliance plan.
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 represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered within 18 months.
Fuel Adjustment Clauses
LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires public hearings at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months.
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 which 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 allows for the recovery of DSM revenues from lost sales associated with the DSM programs. Additionally, LG&E and KU earn an approved return on equity for capital expenditures associated with the residential and commercial load management/demand conservation programs. 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)
In November 2012 and April 2013, LG&E and KU entered into forward-starting interest rate swaps with PPL that hedged the interest payments on new debt that was expected to be issued in 2013. In September 2013, these hedges were terminated and LG&E and KU entered into new forward-starting interest rate swaps with PPL, effectively extending the start date of the prior hedges from September 2013 to December 2013. All of these swaps had terms identical to forward-starting swaps entered into by PPL with third parties. New debt totaling $500 million was issued in November 2013 (LG&E and KU each issued $250 million) and the hedges issued in September were terminated in November 2013. Net cash settlements of $86 million (LG&E and KU each received $43 million) were received on the swaps that were terminated in September and November, which are included in "Cash Flows from Operating Activities" on the Statements of Cash Flows. Net realized gains on these swaps will be returned through regulated rates. As such, the net settlements were reclassified from AOCI to regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the newly issued debt. For the year ended December 31, 2013, there was no hedge ineffectiveness recorded for the interest rate derivatives. See Note 19 for additional information related to the forward-starting interest rate swaps.
(PPL, LKE and LG&E)
In addition to the hedges terminated as a result of the debt issuance, realized amounts associated with LG&E's interest rate swaps, including a terminated swap contract from 2008, are recoverable through rates based on an order from the KPSC, LG&E's unrealized losses 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, as approved by the KPSC.
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, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.
Gas Line Tracker
In the 2012 rate case order, the KPSC approved the GLT rate recovery mechanism. The GLT authorizes LG&E to recover its incremental operating expenses and depreciation, and to earn a 10.25% return on equity for capital associated with the five year gas service riser and leak mitigation program. As part of this 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 adjustment filing to the KPSC to amend rates charged for the differences between the actual costs and actual GLT charges for the preceding year.
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 unfavorable terms relative to current market prices and offsets to regulatory liabilities for those contracts with favorable terms relative to current market prices. These 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 are 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 Associated with Net Deferred Tax Assets
LG&E's and KU's regulatory 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 offsetting deferred tax assets are recognized. For general-purpose financial reporting, these regulatory liabilities and the deferred tax assets are not offset; rather, each is displayed separately.
Regulatory Matters
U.K. Activities (PPL)
Ofgem Review of Line Loss Calculation
Ofgem is currently consulting on the methodology to be used by all network operators to calculate the final line loss incentives and penalties for the DPCR4.  WPD had a $74 million liability recorded at December 31, 2013, compared with $94 million at December 31, 2012. In the fourth quarter of 2012, based on applying the preferred methodology indicated by Ofgem in a consultation issued in November 2012, the liability was reduced by $79 million with a credit recorded in "Utility" revenue on the Statement of Income. In July 2013, Ofgem issued a decision paper on the process to follow for closing out the line loss calculation. Subsequent to the July 2013 decision paper, WPD received additional information from Ofgem. As a result, during 2013, WPD recorded increases of $45 million to the liability with reductions to "Utility" revenue on the Statement of Income. Other changes to the liability in 2013 included reductions of $66 million resulting from refunds being included in tariffs and foreign exchange movements. The potential loss exposure is estimated to be in the range of $74 million to $213 million as of December 31, 2013. PPL cannot predict the outcome of this matter.
European Market Infrastructure Regulation
Regulation No. 648/2012 of the European Parliament and of the Council, commonly referred to as the European Market Infrastructure Regulation (EMIR), entered into force on August 16, 2012 and the European Commission adopted most of the Regulatory Technical Standards without modification in December 2012. The EMIR establishes certain transaction clearing and other recordkeeping requirements for parties to over-the-counter derivatives transactions. Included in the derivative transactions that are subject to EMIR are certain interest rate and currency derivative contracts utilized by WPD. Although the EMIR will potentially impose significant additional recordkeeping requirements on WPD, the effect of the EMIR is not currently expected to have a significant adverse impact on WPD's financial condition or results of operation.
Kentucky Activities
(PPL, LKE, LG&E and KU)
Rate Case Proceedings
In December 2012, the KPSC approved a rate case settlement agreement providing for increases in annual base electricity rates of $34 million for LG&E and $51 million for KU and an increase in annual base gas rates of $15 million for LG&E and authorizes a 10.25% return on equity. The approved rates became effective January 1, 2013.
(PPL, LKE and LG&E)
CPCN Filings
In January 2014, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to build a NGCC generating unit at KU's Green River generating site and a solar generating facility at the E. W. Brown generating site.
Storm Costs
In August 2011, a strong storm hit LG&E's service area causing significant damage and widespread outages for approximately 139,000 customers. LG&E filed an application with the KPSC in September 2011, requesting approval of a regulatory asset recorded to defer, for future recovery, $8 million in incremental operation and maintenance expenses related to the storm restoration. An order was received in December 2011 granting the request. On December 20, 2012, the KPSC, in the approval of the unanimous rate case settlement agreement, authorized regulatory asset recovery effective January 1, 2013, over a five year period.
Pennsylvania Activities (PPL and PPL Electric)
Rate Case Proceeding
In December 2012, the PUC approved a total distribution revenue increase of about $71 million for PPL Electric, including a 10.4% allowed return on equity. The approved rates became effective January 1, 2013.
Storm Damage Expense Rider
In its December 28, 2012 final rate case order, the PUC directed PPL Electric to file a proposed Storm Damage Expense Rider (SDER).  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 included in rates effective January 1, 2014.  In April 2013, parties filed comments opposing the SDER.  PPL Electric and several other parties filed reply comments in May 2013.  In November 2013, the PUC suspended the effective date of the rider to February 28, 2014 and requested additional comments and reply comments on PPL Electric's proposal.  Comments and reply comments have been filed. On February 10, 2014, PPL Electric agreed to an additional suspension of the effective date of the rider to May 1, 2014. This matter remains pending before the PUC.
Act 129
Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet specified goals for reduction in customer electricity usage and peak demand by specified dates. EDCs not meeting the requirements of Act 129 are subject to significant penalties.
Under Act 129, EDCs must file an energy efficiency and conservation plan (EE&C Plan) with the PUC and contract with conservation service providers to implement all or a portion of the EE&C Plan. EDCs are able to recover the costs (capped at 2.0% of the EDC's 2006 revenue) of implementing their EE&C Plans. In October 2009, the PUC approved PPL Electric's Phase 1 EE&C Plan ending May 31, 2013.
Act 129 required EDCs to reduce overall electricity consumption by 1.0% by May 2011 and by 3.0% by May 2013, and reduce peak demand by 4.5% by May 2013. The overall consumption reduction is measured against PUC-forecasted consumption for the twelve months ended May 31, 2010. The peak demand reduction was required to occur for the 100 hours of highest demand, which is determined by actual demand reduction during the June 2012 through September 2012 period. PPL Electric believes it has met the May 2011 and May 2013 overall electricity consumption requirements, and the peak demand reduction requirement based on the results of its November 15, 2013 Act 129 Final Annual Report. PPL Electric does not expect the PUC to formally determine compliance for either the 2011 or 2013 requirements until after the first quarter of 2014.
Act 129 requires the PUC to evaluate the costs and benefits of the EE&C program by November 30, 2013 and adopt additional reductions if the benefits of the program exceed the costs. In August 2012, after receiving input from stakeholders, the PUC issued a Final Implementation Order establishing a three-year Phase II program, ending May 31, 2016, with individual consumption reduction targets for each EDC. PPL Electric's Phase II reduction target is 2.1% of the total energy consumption forecasted by the PUC for the twelve months ended May 31, 2010. The PUC did not establish demand reduction targets for the Phase II program. PPL Electric filed its Phase II EE&C Plan with the PUC on November 15, 2012 and, in March 2013, the PUC approved PPL Electric's Phase II EE&C Plan with minor modifications. PPL Electric filed a Revised Phase II EE&C Plan on May 13, 2013 pursuant to the PUC's March Order. On July 11, 2013, the PUC issued an Order approving PPL Electric's Revised Phase II EE&C Plan. PPL Electric began its Phase II Plan implementation on June 1, 2013. In November 2013, PPL Electric filed 40 modifications to its Phase II Plan which contains programs designed to meet PPL Electric's target of reducing total energy consumption by 2.1%. Parties have filed comments and reply comments on PPL Electric's proposal.
Act 129 also requires Default Service Providers (DSP) to provide electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan through auctions, requests for proposal and bilateral contracts at the sole discretion of the DSP. Act 129 requires a mix of spot market purchases, short-term contracts and long-term contracts (4 to 20 years), with long-term contracts limited to 25% of load unless otherwise approved by the PUC. A DSP is able to recover the costs associated with its default service procurement plan.
The PUC approved PPL Electric's DSP procurement plan for the period January 1, 2011 through May 31, 2013, and PPL Electric has concluded all competitive solicitations to procure power for its PLR obligations under that plan.
The PUC directed all EDCs to file default service procurement plans for the period June 1, 2013 through May 31, 2015. PPL Electric filed its plan in May 2012. In that plan, PPL Electric proposed a process to obtain supply for its default service customers and a number of initiatives designed to encourage more customers to purchase electricity from the competitive retail market. In January 2013, the PUC approved PPL Electric's plan with modifications. PPL Electric filed revised retail competition initiatives and a revised plan consistent with the PUC's January order, and in May 2013, the PUC approved that filing with minor changes. PPL Electric began implementing its revised plan on June 1, 2013. PPL Electric anticipates filing its default service procurement plan for the period beginning June 1, 2015 in the second quarter of 2014.
Smart Meter Rider
Act 129 also requires installation of smart meters for new construction, upon the request of consumers and at their cost, or on a depreciation schedule not exceeding 15 years. Under Act 129, EDCs are able to recover the costs of providing smart metering technology. All of PPL Electric's metered customers currently have advanced meters installed at their service locations capable of many of the functions required under Act 129. PPL Electric continues to conduct pilot projects to evaluate additional applications of its current advanced metering technology pursuant to the requirements of Act 129. PPL Electric recovers the cost of its pilot projects through a cost recovery mechanism, the Smart Meter Rider (SMR). In August 2013, PPL Electric filed with the PUC an annual report describing the actions it was taking under its Smart Meter Plan during 2013 and its planned actions for 2014. PPL Electric also submitted revised SMR charges that became effective January 1, 2014. PPL Electric will submit its final Smart Meter Plan by June 30, 2014.
PUC Investigation of Retail Electricity Market
In April 2011, the PUC opened an investigation of Pennsylvania's retail electricity market to be conducted in two phases. Phase one addressed the status of the existing retail market and explored potential changes. Questions issued by the PUC for phase one of the investigation focused primarily on default service issues. Phase two was initiated in July 2011 to develop specific proposals for changes to the retail market and default service model. From December 2011 through the end of 2012, the PUC issued several orders and other pronouncements related to the investigation. A final implementation order was issued in February 2013, and the PUC created several working groups to address continuing competitive issues. Although the final implementation order contains provisions that will require numerous modifications to PPL Electric's current default service model for retail customers, those modifications are not expected to have a material adverse effect on PPL Electric's results of operations.
Distribution System Improvement Charge
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 begins a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging distribution assets. In August 2012, the PUC issued a Final Implementation Order adopting procedures, guidelines and a model tariff for the implementation of Act 11. Act 11 requires utilities to file an LTIIP as a prerequisite to filing for recovery through the DSIC. The LTIIP is mandated to be a five- to ten-year plan describing projects eligible for inclusion in the DSIC.
In September 2012, PPL Electric filed its LTIIP describing projects eligible for inclusion in the DSIC. The PUC approved the LTIIP on January 10, 2013 and, on January 15, 2013, PPL Electric filed a petition requesting permission to establish a DSIC. Several parties filed responses to PPL Electric's petition. 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 refund 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. The case remains pending before the PUC.
Storm Costs
During 2012, PPL Electric experienced several PUC-reportable storms, including Hurricane Sandy, resulting in total restoration costs of $81 million, of which $61 million were initially recorded in “Other operation and maintenance” on the Statement of Income.  In particular, in late October 2012, PPL Electric experienced widespread significant damage to its distribution network from Hurricane Sandy resulting in total restoration costs of $66 million, of which $50 million were initially recorded in “Other operation and maintenance” on the Statement of Income. Although PPL Electric had storm insurance coverage, the costs incurred from Hurricane Sandy exceeded the policy limits. Probable insurance recoveries recorded during 2012 were $18.25 million, of which $14 million were included in "Other operation and maintenance" on the Statement of Income. At December 31, 2013 and 2012, respectively, $29 million and $28 million was included on the Balance Sheets as a regulatory asset. In February 2013, PPL Electric received an order from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Sandy. See “Storm Damage Expense Rider” above for information regarding PPL Electric's plan to file a proposed Storm Damage Expense Rider with the PUC.
PPL Electric experienced several PUC-reportable storms during 2011 including Hurricane Irene and a late October snow storm. Total restoration costs were $84 million, of which $54 million were initially recorded in "Other operation and maintenance" on the Statement of Income. Although PPL Electric had storm insurance coverage with a PPL affiliate, the costs associated with the unusually high number of PUC-reportable storms exceeded policy limits. Probable insurance recoveries recorded during 2011 were $26.5 million, of which $16 million were included in "Other operation and maintenance" on the Statements of Income. In December 2011, PPL Electric received orders from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Irene and a late October 2011 snowstorm. PPL Electric recorded a regulatory asset of $25 million in December 2011 (offset to "Other operation and maintenance" on the Statement of Income). The PUC granted PPL Electric's recovery of the 2011 storm costs in its final order in the 2012 rate case. Recovery began in January 2013 and will continue over a five-year period.
Federal Matters
FERC Formula Rates (PPL and PPL Electric)
Transmission rates are regulated by the FERC. PPL Electric's transmission revenues are billed in accordance with a FERC-approved PJM open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is calculated, in part, based on financial results as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts.
PPL Electric initiated its formula rate 2012, 2011 and 2010 Annual Updates. Each update was subsequently challenged by a group of municipal customers, which challenges have been opposed by PPL Electric. In August 2011, the FERC issued an order substantially rejecting the 2010 formal challenge and the municipal customers filed a request for rehearing of that order. In September 2012, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues raised in the 2010 and 2011 formal challenges. Settlement conferences were held in late 2012 and early 2013. In February 2013, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues in the 2012 formal challenge and consolidated that challenge with the 2010 and 2011 challenges. PPL Electric filed a request for rehearing of the February order which remains pending before the FERC. PPL Electric and the group of municipal customers have exchanged confidential settlement proposals and PPL Electric anticipates that there will be additional settlement conferences held in 2014. PPL and PPL Electric cannot predict the outcome of the foregoing proceedings, which remain pending before the FERC.
In May 2013, PPL Electric filed its 2013 Annual Update with rates proposed to become effective on June 1, 2013. The rates became effective as proposed, and no party has filed a challenge to the 2013 updated rates.
FERC Formula Rates (KU)
In May 2013, KU submitted to the FERC the annual adjustments to the formula rate, which incorporated certain proposed increases.  These rates became effective as of July 1, 2013.
In September 2013, KU filed an application with the FERC to adjust the formula rate under which KU provides wholesale requirements power sales to 12 municipal customers.  Among other changes, the application requests an amended formula whereby KU would charge cost-based rates with a subsequent true-up to actual costs, replacing the current formula which does not include such a true-up.  KU's application proposed an authorized return on equity of 10.7%.  Subject to regulatory approval, the new formula rate may become effective during the second quarter of 2014.
Louisville Gas And Electric Co [Member]	'
Utility Rate Regulation [Line Items]	'
Utility Rate Regulation	'
	6. Utility Rate Regulation
	Regulatory Assets and Liabilities
	(All Registrants except PPL Energy Supply)
	As discussed in Note 1 and summarized below, 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 KPSC 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 calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets.
	As a result of purchase accounting requirements, certain fair value amounts related to contracts that had favorable or unfavorable terms relative to market were recorded on the Balance Sheets with an offsetting regulatory asset or liability. LG&E and KU recover in customer rates the cost of 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 and 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. Therefore, 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 rate 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 development of municipal rates. Therefore, no return is earned on the related assets.
	(PPL and PPL Electric)
	PPL Electric's distribution base rates are calculated based on a return on rate base (net utility plant plus a cash 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 plant 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 except PPL Energy Supply)
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
	Demand side management			8			1			3			1			5
Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
Noncurrent Regulatory Assets:
	Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
	Storm costs			94			109			51			59			43			50
	Unamortized loss on debt			28			31			18			20			10			11
	Interest rate swaps			44			67			44			67
	AROs			44			26			21			15			23			11
	Other			12			29			5			7			7			22
Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
Current Regulatory Liabilities:
		Environmental cost recovery					$	4											$	4
		Gas supply clause		$	3			4		$	3		$	4
		Fuel adjustment clause			4			1								$	4			1
		Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition 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."
(All Registrants except PPL Energy Supply)
Defined Benefit Plans
Defined benefit plan regulatory assets and liabilities represent the portion of unrecognized transition obligation, prior service cost and net actuarial losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is re-measured. Of the regulatory asset and liability balances recorded, costs of $28 million for PPL, $9 million for PPL Electric, $19 million for LKE, $13 million for LG&E and $6 million for KU are expected to be amortized into net periodic defined benefit costs in 2014.
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 and amortize such costs for regulatory accounting and reporting purposes. Once such authority is granted, PPL Electric, LG&E and KU can request recovery of those expenses in a base rate case.
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. Such costs are being amortized through 2040 for PPL, LKE and KU, and through 2035 for LG&E.
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. See Note 1 for additional information.
PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the deferral of 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 permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply (energy and capacity and ancillary services), as well as administration 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 service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year.
Transmission Formula Rate
PPL Electric's transmission revenues are billed in accordance with a FERC-approved open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is based on prior year expenditures and forecasted current calendar year transmission plant additions. An adjustment to the prior year expenditures is recorded as a regulatory asset or liability.
Universal Service Rider (USR)
PPL Electric's distribution rates permit recovery of applicable costs associated with the universal service programs provided to PPL Electric's residential customers. Universal service programs include low-income programs, such as OnTrack and Winter Relief Assistance Program (WRAP). OnTrack is a special payment program for low-income households within the federal poverty level that have difficulty paying their electric bills. This program is funded by residential customers and administered by community-based organizations. Customers who participate in OnTrack receive assistance in the form of reduced payment arrangements, protection against termination of electric service and referrals to other community programs and services. The WRAP program reduces electric bills and improves living comfort for low-income customers by providing services such as weatherization measures and energy education services. The USR is applied to distribution charges for each customer who receives distribution service under PPL Electric's residential service rate schedules. The USR contains a reconciliation mechanism whereby any over- or under-recovery from the current year is refunded to or recovered from residential customers through the adjustment factor determined for the subsequent year.
Storm Damage Expense
In accordance with the PUC's December 2012 final rate case order, PPL Electric proposed the establishment of a Storm Damage Expense Rider with the PUC. The matter remains open before the PUC. Based on 2013 actual storm experience, PPL Electric established a $14 million regulatory liability at December 31, 2013 for revenues collected from customers to cover storm costs in excess of actual storm costs incurred.
Taxes Recoverable through Future Rates
Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred.
Act 129 Compliance Rider
In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, Phase I of PPL Electric's energy efficiency and conservation plan was 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 beginning 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 Activities" for additional information on Act 129.
(PPL, LKE, LG&E and KU)
Environmental Cost Recovery
Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements which apply to coal combustion wastes and by-products from coal-fired 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. 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. As a result of the settlement agreement in the 2012 rate case, beginning in 2013, LG&E and KU will receive a 10.25% return on equity for all ECR projects included in the 2009 and 2011 compliance plans. In 2012 and 2011, LG&E and KU were authorized to receive a 10.63% return on equity for projects associated with the 2009 compliance plan and a 10.10% return on equity for projects associated with the 2011 compliance plan.
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 represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered within 18 months.
Fuel Adjustment Clauses
LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires public hearings at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months.
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 which 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 allows for the recovery of DSM revenues from lost sales associated with the DSM programs. Additionally, LG&E and KU earn an approved return on equity for capital expenditures associated with the residential and commercial load management/demand conservation programs. 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)
In November 2012 and April 2013, LG&E and KU entered into forward-starting interest rate swaps with PPL that hedged the interest payments on new debt that was expected to be issued in 2013. In September 2013, these hedges were terminated and LG&E and KU entered into new forward-starting interest rate swaps with PPL, effectively extending the start date of the prior hedges from September 2013 to December 2013. All of these swaps had terms identical to forward-starting swaps entered into by PPL with third parties. New debt totaling $500 million was issued in November 2013 (LG&E and KU each issued $250 million) and the hedges issued in September were terminated in November 2013. Net cash settlements of $86 million (LG&E and KU each received $43 million) were received on the swaps that were terminated in September and November, which are included in "Cash Flows from Operating Activities" on the Statements of Cash Flows. Net realized gains on these swaps will be returned through regulated rates. As such, the net settlements were reclassified from AOCI to regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the newly issued debt. For the year ended December 31, 2013, there was no hedge ineffectiveness recorded for the interest rate derivatives. See Note 19 for additional information related to the forward-starting interest rate swaps.
(PPL, LKE and LG&E)
In addition to the hedges terminated as a result of the debt issuance, realized amounts associated with LG&E's interest rate swaps, including a terminated swap contract from 2008, are recoverable through rates based on an order from the KPSC, LG&E's unrealized losses 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, as approved by the KPSC.
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, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.
Gas Line Tracker
In the 2012 rate case order, the KPSC approved the GLT rate recovery mechanism. The GLT authorizes LG&E to recover its incremental operating expenses and depreciation, and to earn a 10.25% return on equity for capital associated with the five year gas service riser and leak mitigation program. As part of this 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 adjustment filing to the KPSC to amend rates charged for the differences between the actual costs and actual GLT charges for the preceding year.
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 unfavorable terms relative to current market prices and offsets to regulatory liabilities for those contracts with favorable terms relative to current market prices. These 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 are 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 Associated with Net Deferred Tax Assets
LG&E's and KU's regulatory 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 offsetting deferred tax assets are recognized. For general-purpose financial reporting, these regulatory liabilities and the deferred tax assets are not offset; rather, each is displayed separately.
Regulatory Matters
U.K. Activities (PPL)
Ofgem Review of Line Loss Calculation
Ofgem is currently consulting on the methodology to be used by all network operators to calculate the final line loss incentives and penalties for the DPCR4.  WPD had a $74 million liability recorded at December 31, 2013, compared with $94 million at December 31, 2012. In the fourth quarter of 2012, based on applying the preferred methodology indicated by Ofgem in a consultation issued in November 2012, the liability was reduced by $79 million with a credit recorded in "Utility" revenue on the Statement of Income. In July 2013, Ofgem issued a decision paper on the process to follow for closing out the line loss calculation. Subsequent to the July 2013 decision paper, WPD received additional information from Ofgem. As a result, during 2013, WPD recorded increases of $45 million to the liability with reductions to "Utility" revenue on the Statement of Income. Other changes to the liability in 2013 included reductions of $66 million resulting from refunds being included in tariffs and foreign exchange movements. The potential loss exposure is estimated to be in the range of $74 million to $213 million as of December 31, 2013. PPL cannot predict the outcome of this matter.
European Market Infrastructure Regulation
Regulation No. 648/2012 of the European Parliament and of the Council, commonly referred to as the European Market Infrastructure Regulation (EMIR), entered into force on August 16, 2012 and the European Commission adopted most of the Regulatory Technical Standards without modification in December 2012. The EMIR establishes certain transaction clearing and other recordkeeping requirements for parties to over-the-counter derivatives transactions. Included in the derivative transactions that are subject to EMIR are certain interest rate and currency derivative contracts utilized by WPD. Although the EMIR will potentially impose significant additional recordkeeping requirements on WPD, the effect of the EMIR is not currently expected to have a significant adverse impact on WPD's financial condition or results of operation.
Kentucky Activities
(PPL, LKE, LG&E and KU)
Rate Case Proceedings
In December 2012, the KPSC approved a rate case settlement agreement providing for increases in annual base electricity rates of $34 million for LG&E and $51 million for KU and an increase in annual base gas rates of $15 million for LG&E and authorizes a 10.25% return on equity. The approved rates became effective January 1, 2013.
(PPL, LKE and LG&E)
CPCN Filings
In January 2014, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to build a NGCC generating unit at KU's Green River generating site and a solar generating facility at the E. W. Brown generating site.
Storm Costs
In August 2011, a strong storm hit LG&E's service area causing significant damage and widespread outages for approximately 139,000 customers. LG&E filed an application with the KPSC in September 2011, requesting approval of a regulatory asset recorded to defer, for future recovery, $8 million in incremental operation and maintenance expenses related to the storm restoration. An order was received in December 2011 granting the request. On December 20, 2012, the KPSC, in the approval of the unanimous rate case settlement agreement, authorized regulatory asset recovery effective January 1, 2013, over a five year period.
Pennsylvania Activities (PPL and PPL Electric)
Rate Case Proceeding
In December 2012, the PUC approved a total distribution revenue increase of about $71 million for PPL Electric, including a 10.4% allowed return on equity. The approved rates became effective January 1, 2013.
Storm Damage Expense Rider
In its December 28, 2012 final rate case order, the PUC directed PPL Electric to file a proposed Storm Damage Expense Rider (SDER).  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 included in rates effective January 1, 2014.  In April 2013, parties filed comments opposing the SDER.  PPL Electric and several other parties filed reply comments in May 2013.  In November 2013, the PUC suspended the effective date of the rider to February 28, 2014 and requested additional comments and reply comments on PPL Electric's proposal.  Comments and reply comments have been filed. On February 10, 2014, PPL Electric agreed to an additional suspension of the effective date of the rider to May 1, 2014. This matter remains pending before the PUC.
Act 129
Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet specified goals for reduction in customer electricity usage and peak demand by specified dates. EDCs not meeting the requirements of Act 129 are subject to significant penalties.
Under Act 129, EDCs must file an energy efficiency and conservation plan (EE&C Plan) with the PUC and contract with conservation service providers to implement all or a portion of the EE&C Plan. EDCs are able to recover the costs (capped at 2.0% of the EDC's 2006 revenue) of implementing their EE&C Plans. In October 2009, the PUC approved PPL Electric's Phase 1 EE&C Plan ending May 31, 2013.
Act 129 required EDCs to reduce overall electricity consumption by 1.0% by May 2011 and by 3.0% by May 2013, and reduce peak demand by 4.5% by May 2013. The overall consumption reduction is measured against PUC-forecasted consumption for the twelve months ended May 31, 2010. The peak demand reduction was required to occur for the 100 hours of highest demand, which is determined by actual demand reduction during the June 2012 through September 2012 period. PPL Electric believes it has met the May 2011 and May 2013 overall electricity consumption requirements, and the peak demand reduction requirement based on the results of its November 15, 2013 Act 129 Final Annual Report. PPL Electric does not expect the PUC to formally determine compliance for either the 2011 or 2013 requirements until after the first quarter of 2014.
Act 129 requires the PUC to evaluate the costs and benefits of the EE&C program by November 30, 2013 and adopt additional reductions if the benefits of the program exceed the costs. In August 2012, after receiving input from stakeholders, the PUC issued a Final Implementation Order establishing a three-year Phase II program, ending May 31, 2016, with individual consumption reduction targets for each EDC. PPL Electric's Phase II reduction target is 2.1% of the total energy consumption forecasted by the PUC for the twelve months ended May 31, 2010. The PUC did not establish demand reduction targets for the Phase II program. PPL Electric filed its Phase II EE&C Plan with the PUC on November 15, 2012 and, in March 2013, the PUC approved PPL Electric's Phase II EE&C Plan with minor modifications. PPL Electric filed a Revised Phase II EE&C Plan on May 13, 2013 pursuant to the PUC's March Order. On July 11, 2013, the PUC issued an Order approving PPL Electric's Revised Phase II EE&C Plan. PPL Electric began its Phase II Plan implementation on June 1, 2013. In November 2013, PPL Electric filed 40 modifications to its Phase II Plan which contains programs designed to meet PPL Electric's target of reducing total energy consumption by 2.1%. Parties have filed comments and reply comments on PPL Electric's proposal.
Act 129 also requires Default Service Providers (DSP) to provide electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan through auctions, requests for proposal and bilateral contracts at the sole discretion of the DSP. Act 129 requires a mix of spot market purchases, short-term contracts and long-term contracts (4 to 20 years), with long-term contracts limited to 25% of load unless otherwise approved by the PUC. A DSP is able to recover the costs associated with its default service procurement plan.
The PUC approved PPL Electric's DSP procurement plan for the period January 1, 2011 through May 31, 2013, and PPL Electric has concluded all competitive solicitations to procure power for its PLR obligations under that plan.
The PUC directed all EDCs to file default service procurement plans for the period June 1, 2013 through May 31, 2015. PPL Electric filed its plan in May 2012. In that plan, PPL Electric proposed a process to obtain supply for its default service customers and a number of initiatives designed to encourage more customers to purchase electricity from the competitive retail market. In January 2013, the PUC approved PPL Electric's plan with modifications. PPL Electric filed revised retail competition initiatives and a revised plan consistent with the PUC's January order, and in May 2013, the PUC approved that filing with minor changes. PPL Electric began implementing its revised plan on June 1, 2013. PPL Electric anticipates filing its default service procurement plan for the period beginning June 1, 2015 in the second quarter of 2014.
Smart Meter Rider
Act 129 also requires installation of smart meters for new construction, upon the request of consumers and at their cost, or on a depreciation schedule not exceeding 15 years. Under Act 129, EDCs are able to recover the costs of providing smart metering technology. All of PPL Electric's metered customers currently have advanced meters installed at their service locations capable of many of the functions required under Act 129. PPL Electric continues to conduct pilot projects to evaluate additional applications of its current advanced metering technology pursuant to the requirements of Act 129. PPL Electric recovers the cost of its pilot projects through a cost recovery mechanism, the Smart Meter Rider (SMR). In August 2013, PPL Electric filed with the PUC an annual report describing the actions it was taking under its Smart Meter Plan during 2013 and its planned actions for 2014. PPL Electric also submitted revised SMR charges that became effective January 1, 2014. PPL Electric will submit its final Smart Meter Plan by June 30, 2014.
PUC Investigation of Retail Electricity Market
In April 2011, the PUC opened an investigation of Pennsylvania's retail electricity market to be conducted in two phases. Phase one addressed the status of the existing retail market and explored potential changes. Questions issued by the PUC for phase one of the investigation focused primarily on default service issues. Phase two was initiated in July 2011 to develop specific proposals for changes to the retail market and default service model. From December 2011 through the end of 2012, the PUC issued several orders and other pronouncements related to the investigation. A final implementation order was issued in February 2013, and the PUC created several working groups to address continuing competitive issues. Although the final implementation order contains provisions that will require numerous modifications to PPL Electric's current default service model for retail customers, those modifications are not expected to have a material adverse effect on PPL Electric's results of operations.
Distribution System Improvement Charge
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 begins a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging distribution assets. In August 2012, the PUC issued a Final Implementation Order adopting procedures, guidelines and a model tariff for the implementation of Act 11. Act 11 requires utilities to file an LTIIP as a prerequisite to filing for recovery through the DSIC. The LTIIP is mandated to be a five- to ten-year plan describing projects eligible for inclusion in the DSIC.
In September 2012, PPL Electric filed its LTIIP describing projects eligible for inclusion in the DSIC. The PUC approved the LTIIP on January 10, 2013 and, on January 15, 2013, PPL Electric filed a petition requesting permission to establish a DSIC. Several parties filed responses to PPL Electric's petition. 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 refund 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. The case remains pending before the PUC.
Storm Costs
During 2012, PPL Electric experienced several PUC-reportable storms, including Hurricane Sandy, resulting in total restoration costs of $81 million, of which $61 million were initially recorded in “Other operation and maintenance” on the Statement of Income.  In particular, in late October 2012, PPL Electric experienced widespread significant damage to its distribution network from Hurricane Sandy resulting in total restoration costs of $66 million, of which $50 million were initially recorded in “Other operation and maintenance” on the Statement of Income. Although PPL Electric had storm insurance coverage, the costs incurred from Hurricane Sandy exceeded the policy limits. Probable insurance recoveries recorded during 2012 were $18.25 million, of which $14 million were included in "Other operation and maintenance" on the Statement of Income. At December 31, 2013 and 2012, respectively, $29 million and $28 million was included on the Balance Sheets as a regulatory asset. In February 2013, PPL Electric received an order from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Sandy. See “Storm Damage Expense Rider” above for information regarding PPL Electric's plan to file a proposed Storm Damage Expense Rider with the PUC.
PPL Electric experienced several PUC-reportable storms during 2011 including Hurricane Irene and a late October snow storm. Total restoration costs were $84 million, of which $54 million were initially recorded in "Other operation and maintenance" on the Statement of Income. Although PPL Electric had storm insurance coverage with a PPL affiliate, the costs associated with the unusually high number of PUC-reportable storms exceeded policy limits. Probable insurance recoveries recorded during 2011 were $26.5 million, of which $16 million were included in "Other operation and maintenance" on the Statements of Income. In December 2011, PPL Electric received orders from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Irene and a late October 2011 snowstorm. PPL Electric recorded a regulatory asset of $25 million in December 2011 (offset to "Other operation and maintenance" on the Statement of Income). The PUC granted PPL Electric's recovery of the 2011 storm costs in its final order in the 2012 rate case. Recovery began in January 2013 and will continue over a five-year period.
Federal Matters
FERC Formula Rates (PPL and PPL Electric)
Transmission rates are regulated by the FERC. PPL Electric's transmission revenues are billed in accordance with a FERC-approved PJM open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is calculated, in part, based on financial results as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts.
PPL Electric initiated its formula rate 2012, 2011 and 2010 Annual Updates. Each update was subsequently challenged by a group of municipal customers, which challenges have been opposed by PPL Electric. In August 2011, the FERC issued an order substantially rejecting the 2010 formal challenge and the municipal customers filed a request for rehearing of that order. In September 2012, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues raised in the 2010 and 2011 formal challenges. Settlement conferences were held in late 2012 and early 2013. In February 2013, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues in the 2012 formal challenge and consolidated that challenge with the 2010 and 2011 challenges. PPL Electric filed a request for rehearing of the February order which remains pending before the FERC. PPL Electric and the group of municipal customers have exchanged confidential settlement proposals and PPL Electric anticipates that there will be additional settlement conferences held in 2014. PPL and PPL Electric cannot predict the outcome of the foregoing proceedings, which remain pending before the FERC.
In May 2013, PPL Electric filed its 2013 Annual Update with rates proposed to become effective on June 1, 2013. The rates became effective as proposed, and no party has filed a challenge to the 2013 updated rates.
FERC Formula Rates (KU)
In May 2013, KU submitted to the FERC the annual adjustments to the formula rate, which incorporated certain proposed increases.  These rates became effective as of July 1, 2013.
In September 2013, KU filed an application with the FERC to adjust the formula rate under which KU provides wholesale requirements power sales to 12 municipal customers.  Among other changes, the application requests an amended formula whereby KU would charge cost-based rates with a subsequent true-up to actual costs, replacing the current formula which does not include such a true-up.  KU's application proposed an authorized return on equity of 10.7%.  Subject to regulatory approval, the new formula rate may become effective during the second quarter of 2014.
Kentucky Utilities Co [Member]	'
Utility Rate Regulation [Line Items]	'
Utility Rate Regulation	'
	6. Utility Rate Regulation
	Regulatory Assets and Liabilities
	(All Registrants except PPL Energy Supply)
	As discussed in Note 1 and summarized below, 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 KPSC 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 calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets.
	As a result of purchase accounting requirements, certain fair value amounts related to contracts that had favorable or unfavorable terms relative to market were recorded on the Balance Sheets with an offsetting regulatory asset or liability. LG&E and KU recover in customer rates the cost of 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 and 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. Therefore, 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 rate 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 development of municipal rates. Therefore, no return is earned on the related assets.
	(PPL and PPL Electric)
	PPL Electric's distribution base rates are calculated based on a return on rate base (net utility plant plus a cash 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 plant 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 except PPL Energy Supply)
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
	Demand side management			8			1			3			1			5
Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
Noncurrent Regulatory Assets:
	Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
	Storm costs			94			109			51			59			43			50
	Unamortized loss on debt			28			31			18			20			10			11
	Interest rate swaps			44			67			44			67
	AROs			44			26			21			15			23			11
	Other			12			29			5			7			7			22
Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
Current Regulatory Liabilities:
		Environmental cost recovery					$	4											$	4
		Gas supply clause		$	3			4		$	3		$	4
		Fuel adjustment clause			4			1								$	4			1
		Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition 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."
(All Registrants except PPL Energy Supply)
Defined Benefit Plans
Defined benefit plan regulatory assets and liabilities represent the portion of unrecognized transition obligation, prior service cost and net actuarial losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is re-measured. Of the regulatory asset and liability balances recorded, costs of $28 million for PPL, $9 million for PPL Electric, $19 million for LKE, $13 million for LG&E and $6 million for KU are expected to be amortized into net periodic defined benefit costs in 2014.
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 and amortize such costs for regulatory accounting and reporting purposes. Once such authority is granted, PPL Electric, LG&E and KU can request recovery of those expenses in a base rate case.
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. Such costs are being amortized through 2040 for PPL, LKE and KU, and through 2035 for LG&E.
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. See Note 1 for additional information.
PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the deferral of 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 permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply (energy and capacity and ancillary services), as well as administration 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 service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year.
Transmission Formula Rate
PPL Electric's transmission revenues are billed in accordance with a FERC-approved open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is based on prior year expenditures and forecasted current calendar year transmission plant additions. An adjustment to the prior year expenditures is recorded as a regulatory asset or liability.
Universal Service Rider (USR)
PPL Electric's distribution rates permit recovery of applicable costs associated with the universal service programs provided to PPL Electric's residential customers. Universal service programs include low-income programs, such as OnTrack and Winter Relief Assistance Program (WRAP). OnTrack is a special payment program for low-income households within the federal poverty level that have difficulty paying their electric bills. This program is funded by residential customers and administered by community-based organizations. Customers who participate in OnTrack receive assistance in the form of reduced payment arrangements, protection against termination of electric service and referrals to other community programs and services. The WRAP program reduces electric bills and improves living comfort for low-income customers by providing services such as weatherization measures and energy education services. The USR is applied to distribution charges for each customer who receives distribution service under PPL Electric's residential service rate schedules. The USR contains a reconciliation mechanism whereby any over- or under-recovery from the current year is refunded to or recovered from residential customers through the adjustment factor determined for the subsequent year.
Storm Damage Expense
In accordance with the PUC's December 2012 final rate case order, PPL Electric proposed the establishment of a Storm Damage Expense Rider with the PUC. The matter remains open before the PUC. Based on 2013 actual storm experience, PPL Electric established a $14 million regulatory liability at December 31, 2013 for revenues collected from customers to cover storm costs in excess of actual storm costs incurred.
Taxes Recoverable through Future Rates
Taxes recoverable through future rates represent the portion of future income taxes that will be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred.
Act 129 Compliance Rider
In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, Phase I of PPL Electric's energy efficiency and conservation plan was 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 beginning 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 Activities" for additional information on Act 129.
(PPL, LKE, LG&E and KU)
Environmental Cost Recovery
Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements which apply to coal combustion wastes and by-products from coal-fired 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. 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. As a result of the settlement agreement in the 2012 rate case, beginning in 2013, LG&E and KU will receive a 10.25% return on equity for all ECR projects included in the 2009 and 2011 compliance plans. In 2012 and 2011, LG&E and KU were authorized to receive a 10.63% return on equity for projects associated with the 2009 compliance plan and a 10.10% return on equity for projects associated with the 2011 compliance plan.
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 represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered within 18 months.
Fuel Adjustment Clauses
LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires public hearings at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months.
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 which 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 allows for the recovery of DSM revenues from lost sales associated with the DSM programs. Additionally, LG&E and KU earn an approved return on equity for capital expenditures associated with the residential and commercial load management/demand conservation programs. 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)
In November 2012 and April 2013, LG&E and KU entered into forward-starting interest rate swaps with PPL that hedged the interest payments on new debt that was expected to be issued in 2013. In September 2013, these hedges were terminated and LG&E and KU entered into new forward-starting interest rate swaps with PPL, effectively extending the start date of the prior hedges from September 2013 to December 2013. All of these swaps had terms identical to forward-starting swaps entered into by PPL with third parties. New debt totaling $500 million was issued in November 2013 (LG&E and KU each issued $250 million) and the hedges issued in September were terminated in November 2013. Net cash settlements of $86 million (LG&E and KU each received $43 million) were received on the swaps that were terminated in September and November, which are included in "Cash Flows from Operating Activities" on the Statements of Cash Flows. Net realized gains on these swaps will be returned through regulated rates. As such, the net settlements were reclassified from AOCI to regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the newly issued debt. For the year ended December 31, 2013, there was no hedge ineffectiveness recorded for the interest rate derivatives. See Note 19 for additional information related to the forward-starting interest rate swaps.
(PPL, LKE and LG&E)
In addition to the hedges terminated as a result of the debt issuance, realized amounts associated with LG&E's interest rate swaps, including a terminated swap contract from 2008, are recoverable through rates based on an order from the KPSC, LG&E's unrealized losses 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, as approved by the KPSC.
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, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.
Gas Line Tracker
In the 2012 rate case order, the KPSC approved the GLT rate recovery mechanism. The GLT authorizes LG&E to recover its incremental operating expenses and depreciation, and to earn a 10.25% return on equity for capital associated with the five year gas service riser and leak mitigation program. As part of this 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 adjustment filing to the KPSC to amend rates charged for the differences between the actual costs and actual GLT charges for the preceding year.
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 unfavorable terms relative to current market prices and offsets to regulatory liabilities for those contracts with favorable terms relative to current market prices. These 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 are 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 Associated with Net Deferred Tax Assets
LG&E's and KU's regulatory 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 offsetting deferred tax assets are recognized. For general-purpose financial reporting, these regulatory liabilities and the deferred tax assets are not offset; rather, each is displayed separately.
Regulatory Matters
U.K. Activities (PPL)
Ofgem Review of Line Loss Calculation
Ofgem is currently consulting on the methodology to be used by all network operators to calculate the final line loss incentives and penalties for the DPCR4.  WPD had a $74 million liability recorded at December 31, 2013, compared with $94 million at December 31, 2012. In the fourth quarter of 2012, based on applying the preferred methodology indicated by Ofgem in a consultation issued in November 2012, the liability was reduced by $79 million with a credit recorded in "Utility" revenue on the Statement of Income. In July 2013, Ofgem issued a decision paper on the process to follow for closing out the line loss calculation. Subsequent to the July 2013 decision paper, WPD received additional information from Ofgem. As a result, during 2013, WPD recorded increases of $45 million to the liability with reductions to "Utility" revenue on the Statement of Income. Other changes to the liability in 2013 included reductions of $66 million resulting from refunds being included in tariffs and foreign exchange movements. The potential loss exposure is estimated to be in the range of $74 million to $213 million as of December 31, 2013. PPL cannot predict the outcome of this matter.
European Market Infrastructure Regulation
Regulation No. 648/2012 of the European Parliament and of the Council, commonly referred to as the European Market Infrastructure Regulation (EMIR), entered into force on August 16, 2012 and the European Commission adopted most of the Regulatory Technical Standards without modification in December 2012. The EMIR establishes certain transaction clearing and other recordkeeping requirements for parties to over-the-counter derivatives transactions. Included in the derivative transactions that are subject to EMIR are certain interest rate and currency derivative contracts utilized by WPD. Although the EMIR will potentially impose significant additional recordkeeping requirements on WPD, the effect of the EMIR is not currently expected to have a significant adverse impact on WPD's financial condition or results of operation.
Kentucky Activities
(PPL, LKE, LG&E and KU)
Rate Case Proceedings
In December 2012, the KPSC approved a rate case settlement agreement providing for increases in annual base electricity rates of $34 million for LG&E and $51 million for KU and an increase in annual base gas rates of $15 million for LG&E and authorizes a 10.25% return on equity. The approved rates became effective January 1, 2013.
(PPL, LKE and LG&E)
CPCN Filings
In January 2014, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to build a NGCC generating unit at KU's Green River generating site and a solar generating facility at the E. W. Brown generating site.
Storm Costs
In August 2011, a strong storm hit LG&E's service area causing significant damage and widespread outages for approximately 139,000 customers. LG&E filed an application with the KPSC in September 2011, requesting approval of a regulatory asset recorded to defer, for future recovery, $8 million in incremental operation and maintenance expenses related to the storm restoration. An order was received in December 2011 granting the request. On December 20, 2012, the KPSC, in the approval of the unanimous rate case settlement agreement, authorized regulatory asset recovery effective January 1, 2013, over a five year period.
Pennsylvania Activities (PPL and PPL Electric)
Rate Case Proceeding
In December 2012, the PUC approved a total distribution revenue increase of about $71 million for PPL Electric, including a 10.4% allowed return on equity. The approved rates became effective January 1, 2013.
Storm Damage Expense Rider
In its December 28, 2012 final rate case order, the PUC directed PPL Electric to file a proposed Storm Damage Expense Rider (SDER).  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 included in rates effective January 1, 2014.  In April 2013, parties filed comments opposing the SDER.  PPL Electric and several other parties filed reply comments in May 2013.  In November 2013, the PUC suspended the effective date of the rider to February 28, 2014 and requested additional comments and reply comments on PPL Electric's proposal.  Comments and reply comments have been filed. On February 10, 2014, PPL Electric agreed to an additional suspension of the effective date of the rider to May 1, 2014. This matter remains pending before the PUC.
Act 129
Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet specified goals for reduction in customer electricity usage and peak demand by specified dates. EDCs not meeting the requirements of Act 129 are subject to significant penalties.
Under Act 129, EDCs must file an energy efficiency and conservation plan (EE&C Plan) with the PUC and contract with conservation service providers to implement all or a portion of the EE&C Plan. EDCs are able to recover the costs (capped at 2.0% of the EDC's 2006 revenue) of implementing their EE&C Plans. In October 2009, the PUC approved PPL Electric's Phase 1 EE&C Plan ending May 31, 2013.
Act 129 required EDCs to reduce overall electricity consumption by 1.0% by May 2011 and by 3.0% by May 2013, and reduce peak demand by 4.5% by May 2013. The overall consumption reduction is measured against PUC-forecasted consumption for the twelve months ended May 31, 2010. The peak demand reduction was required to occur for the 100 hours of highest demand, which is determined by actual demand reduction during the June 2012 through September 2012 period. PPL Electric believes it has met the May 2011 and May 2013 overall electricity consumption requirements, and the peak demand reduction requirement based on the results of its November 15, 2013 Act 129 Final Annual Report. PPL Electric does not expect the PUC to formally determine compliance for either the 2011 or 2013 requirements until after the first quarter of 2014.
Act 129 requires the PUC to evaluate the costs and benefits of the EE&C program by November 30, 2013 and adopt additional reductions if the benefits of the program exceed the costs. In August 2012, after receiving input from stakeholders, the PUC issued a Final Implementation Order establishing a three-year Phase II program, ending May 31, 2016, with individual consumption reduction targets for each EDC. PPL Electric's Phase II reduction target is 2.1% of the total energy consumption forecasted by the PUC for the twelve months ended May 31, 2010. The PUC did not establish demand reduction targets for the Phase II program. PPL Electric filed its Phase II EE&C Plan with the PUC on November 15, 2012 and, in March 2013, the PUC approved PPL Electric's Phase II EE&C Plan with minor modifications. PPL Electric filed a Revised Phase II EE&C Plan on May 13, 2013 pursuant to the PUC's March Order. On July 11, 2013, the PUC issued an Order approving PPL Electric's Revised Phase II EE&C Plan. PPL Electric began its Phase II Plan implementation on June 1, 2013. In November 2013, PPL Electric filed 40 modifications to its Phase II Plan which contains programs designed to meet PPL Electric's target of reducing total energy consumption by 2.1%. Parties have filed comments and reply comments on PPL Electric's proposal.
Act 129 also requires Default Service Providers (DSP) to provide electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan through auctions, requests for proposal and bilateral contracts at the sole discretion of the DSP. Act 129 requires a mix of spot market purchases, short-term contracts and long-term contracts (4 to 20 years), with long-term contracts limited to 25% of load unless otherwise approved by the PUC. A DSP is able to recover the costs associated with its default service procurement plan.
The PUC approved PPL Electric's DSP procurement plan for the period January 1, 2011 through May 31, 2013, and PPL Electric has concluded all competitive solicitations to procure power for its PLR obligations under that plan.
The PUC directed all EDCs to file default service procurement plans for the period June 1, 2013 through May 31, 2015. PPL Electric filed its plan in May 2012. In that plan, PPL Electric proposed a process to obtain supply for its default service customers and a number of initiatives designed to encourage more customers to purchase electricity from the competitive retail market. In January 2013, the PUC approved PPL Electric's plan with modifications. PPL Electric filed revised retail competition initiatives and a revised plan consistent with the PUC's January order, and in May 2013, the PUC approved that filing with minor changes. PPL Electric began implementing its revised plan on June 1, 2013. PPL Electric anticipates filing its default service procurement plan for the period beginning June 1, 2015 in the second quarter of 2014.
Smart Meter Rider
Act 129 also requires installation of smart meters for new construction, upon the request of consumers and at their cost, or on a depreciation schedule not exceeding 15 years. Under Act 129, EDCs are able to recover the costs of providing smart metering technology. All of PPL Electric's metered customers currently have advanced meters installed at their service locations capable of many of the functions required under Act 129. PPL Electric continues to conduct pilot projects to evaluate additional applications of its current advanced metering technology pursuant to the requirements of Act 129. PPL Electric recovers the cost of its pilot projects through a cost recovery mechanism, the Smart Meter Rider (SMR). In August 2013, PPL Electric filed with the PUC an annual report describing the actions it was taking under its Smart Meter Plan during 2013 and its planned actions for 2014. PPL Electric also submitted revised SMR charges that became effective January 1, 2014. PPL Electric will submit its final Smart Meter Plan by June 30, 2014.
PUC Investigation of Retail Electricity Market
In April 2011, the PUC opened an investigation of Pennsylvania's retail electricity market to be conducted in two phases. Phase one addressed the status of the existing retail market and explored potential changes. Questions issued by the PUC for phase one of the investigation focused primarily on default service issues. Phase two was initiated in July 2011 to develop specific proposals for changes to the retail market and default service model. From December 2011 through the end of 2012, the PUC issued several orders and other pronouncements related to the investigation. A final implementation order was issued in February 2013, and the PUC created several working groups to address continuing competitive issues. Although the final implementation order contains provisions that will require numerous modifications to PPL Electric's current default service model for retail customers, those modifications are not expected to have a material adverse effect on PPL Electric's results of operations.
Distribution System Improvement Charge
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 begins a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging distribution assets. In August 2012, the PUC issued a Final Implementation Order adopting procedures, guidelines and a model tariff for the implementation of Act 11. Act 11 requires utilities to file an LTIIP as a prerequisite to filing for recovery through the DSIC. The LTIIP is mandated to be a five- to ten-year plan describing projects eligible for inclusion in the DSIC.
In September 2012, PPL Electric filed its LTIIP describing projects eligible for inclusion in the DSIC. The PUC approved the LTIIP on January 10, 2013 and, on January 15, 2013, PPL Electric filed a petition requesting permission to establish a DSIC. Several parties filed responses to PPL Electric's petition. 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 refund 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. The case remains pending before the PUC.
Storm Costs
During 2012, PPL Electric experienced several PUC-reportable storms, including Hurricane Sandy, resulting in total restoration costs of $81 million, of which $61 million were initially recorded in “Other operation and maintenance” on the Statement of Income.  In particular, in late October 2012, PPL Electric experienced widespread significant damage to its distribution network from Hurricane Sandy resulting in total restoration costs of $66 million, of which $50 million were initially recorded in “Other operation and maintenance” on the Statement of Income. Although PPL Electric had storm insurance coverage, the costs incurred from Hurricane Sandy exceeded the policy limits. Probable insurance recoveries recorded during 2012 were $18.25 million, of which $14 million were included in "Other operation and maintenance" on the Statement of Income. At December 31, 2013 and 2012, respectively, $29 million and $28 million was included on the Balance Sheets as a regulatory asset. In February 2013, PPL Electric received an order from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Sandy. See “Storm Damage Expense Rider” above for information regarding PPL Electric's plan to file a proposed Storm Damage Expense Rider with the PUC.
PPL Electric experienced several PUC-reportable storms during 2011 including Hurricane Irene and a late October snow storm. Total restoration costs were $84 million, of which $54 million were initially recorded in "Other operation and maintenance" on the Statement of Income. Although PPL Electric had storm insurance coverage with a PPL affiliate, the costs associated with the unusually high number of PUC-reportable storms exceeded policy limits. Probable insurance recoveries recorded during 2011 were $26.5 million, of which $16 million were included in "Other operation and maintenance" on the Statements of Income. In December 2011, PPL Electric received orders from the PUC granting permission to defer qualifying storm costs in excess of insurance recoveries associated with Hurricane Irene and a late October 2011 snowstorm. PPL Electric recorded a regulatory asset of $25 million in December 2011 (offset to "Other operation and maintenance" on the Statement of Income). The PUC granted PPL Electric's recovery of the 2011 storm costs in its final order in the 2012 rate case. Recovery began in January 2013 and will continue over a five-year period.
Federal Matters
FERC Formula Rates (PPL and PPL Electric)
Transmission rates are regulated by the FERC. PPL Electric's transmission revenues are billed in accordance with a FERC-approved PJM open access transmission tariff that utilizes a formula-based rate recovery mechanism. The formula rate is calculated, in part, based on financial results as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts.
PPL Electric initiated its formula rate 2012, 2011 and 2010 Annual Updates. Each update was subsequently challenged by a group of municipal customers, which challenges have been opposed by PPL Electric. In August 2011, the FERC issued an order substantially rejecting the 2010 formal challenge and the municipal customers filed a request for rehearing of that order. In September 2012, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues raised in the 2010 and 2011 formal challenges. Settlement conferences were held in late 2012 and early 2013. In February 2013, the FERC issued an order setting for evidentiary hearings and settlement judge procedures a number of issues in the 2012 formal challenge and consolidated that challenge with the 2010 and 2011 challenges. PPL Electric filed a request for rehearing of the February order which remains pending before the FERC. PPL Electric and the group of municipal customers have exchanged confidential settlement proposals and PPL Electric anticipates that there will be additional settlement conferences held in 2014. PPL and PPL Electric cannot predict the outcome of the foregoing proceedings, which remain pending before the FERC.
In May 2013, PPL Electric filed its 2013 Annual Update with rates proposed to become effective on June 1, 2013. The rates became effective as proposed, and no party has filed a challenge to the 2013 updated rates.
FERC Formula Rates (KU)
In May 2013, KU submitted to the FERC the annual adjustments to the formula rate, which incorporated certain proposed increases.  These rates became effective as of July 1, 2013.
In September 2013, KU filed an application with the FERC to adjust the formula rate under which KU provides wholesale requirements power sales to 12 municipal customers.  Among other changes, the application requests an amended formula whereby KU would charge cost-based rates with a subsequent true-up to actual costs, replacing the current formula which does not include such a true-up.  KU's application proposed an authorized return on equity of 10.7%.  Subject to regulatory approval, the new formula rate may become effective during the second quarter of 2014.

Financing_Activities

Financing Activities	12 Months Ended
	Dec. 31, 2013
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 backup to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Energy Supply, PPL Electric, LKE, LG&E and KU also apply to PPL and the credit facilities and commercial paper programs of LG&E and KU also apply to LKE. The amounts borrowed below are recorded as "Short-term debt" on the Balance Sheets. The following credit facilities were in place at:
								December 31, 2013														December 31, 2012
																	Letters of							Letters of
																	Credit Issued							Credit Issued
																	and							and
																	Commercial							Commercial
								Expiration									Paper			Unused				Paper
								Date			Capacity			Borrowed			Backup			Capacity		Borrowed		Backup
	PPL
	U.K.
		PPL WW Syndicated
			Credit Facility (a) (d)						Dec. 2016		£	210		£	103					£	107	£	106
		WPD (South West)
			Syndicated Credit Facility (a) (d)						Jan. 2017			245									245
		WPD (East Midlands)
			Syndicated Credit Facility (a) (b) (d)						Apr. 2016			300									300
		WPD (West Midlands)
			Syndicated Credit Facility (a) (b) (d)						Apr. 2016			300									300
		Uncommitted Credit Facilities										84					£	5			79			£	4
				Total U.K. Credit Facilities (c)							£	1,139		£	103		£	5		£	1,031	£	106	£	4
	U.S.
		PPL Capital Funding
			Syndicated Credit Facility (d) (e) (g)						Nov. 2018		$	300		$	270					$	30
	PPL Energy Supply
		Syndicated Credit Facility (d) (e)							Nov. 2017		$	3,000					$	29		$	2,971			$	499
		Letter of Credit Facility (e)							Mar. 2014			150						138			12				132
		Uncommitted Credit Facilities (e)										175						77			98				40
				Total PPL Energy Supply Credit Facilities							$	3,325					$	244		$	3,081			$	671
	PPL Electric
		Syndicated Credit Facility (d) (e)							Oct. 2017		$	300					$	21		$	279			$	1
	LKE
		Syndicated Credit Facility (d) (e) (g)							Oct. 2018		$	75		$	75
	LG&E
		Syndicated Credit Facility (d) (e)							Nov. 2017		$	500					$	20		$	480			$	55
	KU
		Syndicated Credit Facility (d) (e)							Nov. 2017		$	400					$	150		$	250			$	70
		Letter of Credit Facility (d) (e) (f)							May-16			198						198							198
				Total KU Credit Facilities							$	598					$	348		$	250			$	268
	(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)       Under these facilities, WPD (East Midlands) and WPD (West Midlands) each have the ability to request the lenders to issue up to £80 million of letters of credit in lieu of borrowing.
	(c)       PPL WW's amounts borrowed at December 31, 2013 and 2012 were USD-denominated borrowings of $166 million and $171 million, which equated to £103 million and £106 million at the time of the borrowings and bore interest at 1.87% and 0.85%. At December 31, 2013, the unused capacity of WPD's credit facilities was approximately $1.7 billion.
	(d)       Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin.
	(e)       The facilities contain a financial covenant requiring debt to total capitalization not to exceed 65% for PPL Energy Supply and 70% for PPL, 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 credit facilities and subject to certain conditions, PPL Energy Supply may request that its facility's capacity be increased by up to $500 million, PPL Electric and KU each may request up to a $100 million increase in its facility's capacity and LKE may request up to a $25 million increase in its facility's capacity.
	(f)       KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted to loans rather than requiring immediate payment.
	(g)       PPL Capital Funding's and LKE's borrowings at December 31, 2013 bore interest at 1.79% and 1.67%, respectively.
	PPL Energy Supply, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, as necessary. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's Syndicated Credit Facility. The following commercial paper programs were in place at:
								December 31, 2013												December 31, 2012
								Weighted -						Commercial						Weighted -		Commercial
								Average						Paper			Unused			Average		Paper
								Interest Rate			Capacity			Issuances			Capacity			Interest Rate		Issuances
		PPL Energy Supply									$	750					$	750			0.50%	$	356
		PPL Electric							0.23%			300		$	20			280
		LG&E							0.29%			350			20			330			0.42%		55
		KU							0.32%			350			150			200			0.42%		70
				Total							$	1,750		$	190		$	1,560				$	481
	(PPL and PPL Energy Supply)
	PPL Energy Supply maintains a $500 million Facility Agreement expiring June 2017, whereby PPL Energy Supply has the ability to request up to $500 million of committed letter of credit capacity at fees to be agreed upon at the time of each request, based on certain market conditions. At December 31, 2013, PPL Energy Supply has not requested any capacity for the issuance of letters of credit under this arrangement.
	PPL Energy Supply, PPL EnergyPlus, PPL Montour and PPL Brunner Island maintain an $800 million secured energy marketing and trading facility, whereby PPL EnergyPlus will receive credit to be applied to satisfy collateral posting obligations related to its energy marketing and trading activities with counterparties participating in the facility. The credit amount is guaranteed by PPL Energy Supply, PPL Montour and PPL Brunner Island. PPL Montour and PPL Brunner Island have granted liens on their respective generating facilities to secure any amount they may owe under their guarantees, which had an aggregate carrying value of $2.7 billion at December 31, 2013. The facility expires in November 2018, but is subject to automatic one-year renewals under certain conditions. There were no secured obligations outstanding under this facility at December 31, 2013.
	(All Registrants except PPL)
	See Note 16 for discussion of intercompany borrowings.
2011 Bridge Facility (PPL)
In March 2011, concurrently and in connection with entering into the agreement to acquire WPD Midlands, PPL Capital Funding and PPL WEM, as borrowers, and PPL, as guarantor, entered into a 364-day unsecured £3.6 billion bridge facility to fund the acquisition and pay certain fees and expenses in connection with the acquisition. During 2011, PPL incurred $44 million of fees in connection with establishing the 2011 Bridge Facility, which is reflected in "Interest Expense" on the Statement of Income. On April 1, 2011, concurrent with the closing of the WPD Midlands acquisition, PPL Capital Funding borrowed an aggregate of £1.75 billion and PPL WEM borrowed £1.85 billion under the 2011 Bridge Facility. Borrowings bore interest at approximately 2.62%, determined by one-month LIBOR rates plus a spread, based on PPL Capital Funding's senior unsecured debt rating and the length of time from the date of the acquisition closing that borrowings were outstanding. See Note 10 for additional information on the acquisition.
In accordance with the terms of the 2011 Bridge Facility, PPL Capital Funding's borrowings of £1.75 billion were repaid with approximately $2.8 billion of proceeds received from PPL's issuance of common stock and 2011 Equity Units in April 2011. In April 2011, PPL WEM repaid £650 million of its 2011 Bridge Facility borrowing. Such repayment was funded primarily with proceeds received from PPL WEM's issuance of senior notes. In May 2011, PPL WEM repaid the remaining £1.2 billion of borrowings then-outstanding under the 2011 Bridge Facility, primarily with the proceeds from senior notes issued by WPD (East Midlands) and WPD (West Midlands).
In anticipation of the repayment of a portion of the borrowings under the 2011 Bridge Facility with U.S. dollar proceeds received from PPL's issuance of common stock and 2011 Equity Units and PPL WEM's issuance of U.S. dollar-denominated senior notes, PPL entered into forward contracts to purchase GBP in order to economically hedge the foreign currency exchange rate risk related to the repayment. See Note 19 for additional information.
Long-term Debt (All Registrants)
				Weighted-Average				December 31,
				Rate		Maturities		2013			2012
PPL
U.S.
	Senior Unsecured Notes (a)			4.31%		2014 - 2043		$	5,568		$	4,506
	Senior Secured Notes/First Mortgage Bonds (b) (c) (d) (e)			3.80%		2015 - 2043			5,823			5,587
	Junior Subordinated Notes			5.29%		2019 - 2073			1,908			2,608
	Other			6.95%		2014 - 2020			15			15
			Total U.S. Long-term Debt						13,314			12,716
U.K.
	Senior Unsecured Notes (f)			5.53%		2016 - 2040			6,872			6,111
	Index-linked Senior Unsecured Notes (g)			1.83%		2043 - 2056			749			608
			Total U.K. Long-term Debt (h)						7,621			6,719
			Total Long-term Debt Before Adjustments						20,935			19,435
	Fair market value adjustments								23			78
	Unamortized premium and (discount), net								-51			-37
			Total Long-term Debt						20,907			19,476
	Less current portion of Long-term Debt								315			751
			Total Long-term Debt, noncurrent					$	20,592		$	18,725
PPL Energy Supply
	Senior Unsecured Notes (a)			5.32%		2014 - 2038		$	2,493		$	2,581
	Senior Secured Notes (b)			8.86%		2025			49			663
	Other			6.00%		2020			5			5
			Total Long-term Debt Before Adjustments						2,547			3,249
	Fair market value adjustments								-22			22
	Unamortized premium and (discount), net											1
			Total Long-term Debt						2,525			3,272
	Less current portion of Long-term Debt								304			751
			Total Long-term Debt, noncurrent					$	2,221		$	2,521
PPL Electric
	Senior Secured Notes/First Mortgage Bonds (c) (d)			4.63%		2015 - 2043		$	2,314		$	1,964
	Other			7.38%		2014			10			10
			Total Long-term Debt Before Adjustments						2,324			1,974
	Unamortized discount								-9			-7
			Total Long-term Debt						2,315			1,967
	Less current portion of Long-term Debt								10
			Total Long-term Debt, noncurrent					$	2,305		$	1,967
LKE
	Senior Unsecured Notes			3.31%		2015 - 2021		$	1,125		$	1,125
	Senior Secured Notes/First Mortgage Bonds (c) (e)			3.18%		2015 - 2043			3,460			2,960
			Total Long-term Debt Before Adjustments						4,585			4,085
	Fair market value adjustments								-1			7
	Unamortized discount								-19			-17
			Total Long-term Debt					$	4,565		$	4,075
LG&E
	Senior Secured Notes/First Mortgage Bonds (c) (e)			2.77%		2015 - 2043		$	1,359		$	1,109
			Total Long-term Debt Before Adjustments						1,359			1,109
	Fair market value adjustments								-1			6
	Unamortized discount								-5			-3
			Total Long-term Debt					$	1,353		$	1,112
KU
	Senior Secured Notes/First Mortgage Bonds (c) (e)			3.44%		2015 - 2043		$	2,101		$	1,851
			Total Long-term Debt Before Adjustments						2,101			1,851
	Fair market value adjustments								1			1
	Unamortized discount								-11			-10
			Total Long-term Debt					$	2,091		$	1,842
(a)       Includes $300 million of 5.70% REset Put Securities due 2035 (REPS). The REPS bear interest at a rate of 5.70% per annum to, but excluding, October 15, 2015 (Remarketing Date). The REPS are required to be put by existing holders on the Remarketing Date either for (a) purchase and remarketing by a designated remarketing dealer or (b) repurchase by PPL Energy Supply. If the remarketing dealer elects to purchase the REPS for remarketing, it will purchase the REPS at 100% of the principal amount, and the REPS will bear interest on and after the Remarketing Date at a new fixed rate per annum determined in the remarketing. PPL Energy Supply has the right to terminate the remarketing process. If the remarketing is terminated at the option of PPL Energy Supply or under certain other circumstances, including the occurrence of an event of default by PPL Energy Supply under the related indenture or a failed remarketing for certain specified reasons, PPL Energy Supply will be required to pay the remarketing dealer a settlement amount as calculated in accordance with the related remarketing agreement.
(b)       2012 includes lease financing consolidated through a VIE which was repaid in 2013. See Note 22 for additional information.
(c)       Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $5.1 billion and $4.3 billion at December 31, 2013 and 2012.
Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $3.2 billion and $2.7 billion at December 31, 2013 and December 31, 2012.
Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $5.1 billion and $4.4 billion at December 31, 2013 and December 31, 2012.
(d)       Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (c) above. This amount includes $224 million that may be redeemed 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.
(e)       Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amount, 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 (c) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate.
At December 31, 2013, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $321 million for LKE, comprised of $294 million and $27 million for LG&E and KU. At December 31, 2013, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $604 million for LKE, comprised of $280 million and $324 million for LG&E and KU.
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 process. 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 variable rate tax-exempt revenue bonds totaling $348 million at December 31, 2013 ($120 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.
(f)       Includes £225 million ($368 million at December 31, 2013) of notes that may be redeemed, in total but not in part, on December 21, 2026, at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. Government bond.
(g)       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 principal amounts from 2012 to 2013 was an increase of approximately £12 million ($20 million) resulting from inflation. In addition, this amount includes £225 million ($368 million at December 31, 2013) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026, at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nominated U.K. government bond.
(h)       Includes £3.8 billion ($6.2 billion at December 31, 2013) of notes that may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the notes are withdrawn by any of the rating agencies (Moody's, S&P or Fitch) or reduced to a non-investment grade rating of Ba1 or BB+ in connection with a restructuring event which includes the loss of, or a material adverse change to, the distribution licenses under which the issuer operates.
None of the outstanding debt securities noted above have sinking fund requirements. The aggregate maturities of long-term debt for the periods 2014 through 2018 and thereafter are as follows.
					PPL
					Energy			PPL
		PPL			Supply			Electric			LKE			LG&E			KU
2014		$	314		$	304		$	10
2015			1,304			304			100		$	900		$	250		$	250
2016			814			354
2017			104			4
2018			653			403
Thereafter			17,746			1,178			2,214			3,685			1,109			1,851
Total		$	20,935		$	2,547		$	2,324		$	4,585		$	1,359		$	2,101
Long-term Debt and Equity Securities Activities
(PPL)
In connection with an April 2012 registered public offering of 9.9 million shares of PPL common stock, PPL entered into forward sale agreements with two counterparties. In conjunction with that offering, the underwriters exercised an overallotment option and PPL entered into additional forward sale agreements covering 591 thousand shares of PPL common stock.
In April 2013, PPL settled the initial forward sale agreements by issuing 8.4 million shares of PPL common stock and cash settling the remaining 1.5 million shares. PPL received net cash proceeds of $205 million, which was calculated based on an initial forward price of $27.02 per share, reduced during the period the contracts were outstanding as specified in the forward sale agreements. PPL used the net proceeds to repay short-term debt obligations and for other general corporate purposes. In May 2013, PPL cash settled the forward sale agreements covering the 591 thousand remaining shares for $4 million.
In March 2013, PPL Capital Funding issued $450 million of 5.90% Junior Subordinated Notes due 2073. PPL Capital Funding received proceeds of $436 million, net of underwriting fees, which were loaned to or invested in affiliates of PPL Capital Funding and used to fund their capital expenditures and for other general corporate purposes.
In September and October 2013, WPD (East Midlands) issued £40 million and £25 million aggregate principal amount of 1.676% Index-linked Senior Notes due 2052, which equated to $64 million and $40 million at the time of issuance. The proceeds were used to fund capital expenditures and for other general corporate purposes.
In October 2013, WPD (West Midlands) issued £400 million aggregate principal amount of 3.875% Senior Notes due 2024. WPD (West Midlands) received proceeds of £394 million, which equated to $637 million at the time of issuance, net of a discount and underwriting fees. The net proceeds will be used to fund capital expenditures and for other general corporate purposes.
In 2013, PPL repurchased 2.4 million shares of its common stock for $74 million to offset the 2013 issuances of common stock under stock-based compensation plans, ESOP and DRIP. These repurchases were recorded as a reduction to "Additional paid-in capital" on the Balance Sheet.
(PPL and PPL Energy Supply)
In February 2013, PPL Energy Supply completed an offer to exchange up to all, but not less than a majority, of PPL Ironwood's 8.857% Senior Secured Bonds due 2025 (Ironwood Bonds), for newly issued PPL Energy Supply Senior Notes, Series 4.60% due 2021. A total of $167 million aggregate principal amount of outstanding Ironwood Bonds was exchanged for $212 million aggregate principal amount of Senior Notes, Series 4.60% due 2021. This transaction was accounted for as a modification of the existing debt; therefore, the amount of debt on the Balance Sheet remained at $167 million and will be accreted to $212 million over the life of the new Senior Notes. No gain or loss was recorded and the exchange was considered non-cash activity that was excluded from the 2013 Statement of Cash Flows.
In July 2013, PPL Energy Supply repaid the entire $300 million principal amount of its 6.30% Senior Notes upon maturity.
In December 2013, the entire $284 million and $153 million principal amounts of the 8.05% and 8.30% Senior Notes were repaid upon maturity in connection with the Lower Mt. Bethel lease termination. See Note 22 for additional information.
(PPL and PPL Electric)
In July 2013, PPL Electric issued $350 million of 4.75% First Mortgage Bonds due 2043. PPL Electric received proceeds of $345 million, net of a discount and underwriting fees, which were used for capital expenditures, to fund pension obligations and for other general corporate purposes.
(PPL, LKE, LG&E and KU)
In November 2013, LG&E and KU each issued $250 million of 4.65% First Mortgage Bonds due 2043. LG&E and KU each received proceeds of $246 million, net of discounts and underwriting fees, which were used for repayment of short-term debt, including commercial paper, for capital expenditures and for other general corporate purposes.
(PPL)
2010 Equity Units
During 2013, several events occurred related to the 2010 Equity Units. 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 for 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 Statement of Income. The transaction was considered non-cash activity that was excluded from the 2013 Statement of Cash Flows. 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 obligations and for other general corporate purposes.
2011 Equity Units
In April 2011, in connection with the acquisition of WPD Midlands, PPL issued 92 million shares of its common stock at a public offering price of $25.30 per share, for a total of $2.328 billion. Proceeds from the issuance were $2.258 billion, net of the $70 million underwriting discount. PPL also issued 19.55 million 2011 Equity Units at a stated amount per unit of $50.00 for a total of $978 million. Proceeds from the issuance were $948 million, net of the $30 million underwriting discount. PPL used the net proceeds to repay PPL Capital Funding's borrowings under the 2011 Bridge Facility, as discussed above, to pay certain acquisition-related fees and expenses and for general corporate purposes.
Each 2011 Equity Unit consists of a 2011 Purchase Contract and, initially, a 5.0% undivided beneficial ownership interest in $1,000 principal amount of PPL Capital Funding 4.32% Junior Subordinated Notes due 2019 (2019 Notes).
Each 2011 Purchase Contract obligates the holder to purchase, and PPL to sell, for $50.00 a number of shares of PPL common stock to be determined by the average VWAP of PPL's common stock for the 20-trading day period ending on the third trading day prior to May 1, 2014, subject to antidilution adjustments and an early settlement upon a Fundamental Change as follows:
·       if the average VWAP equals or exceeds approximately $30.99, then 1.6133 shares (a minimum of 31,540,015 shares);
·       if the average VWAP is less than approximately $30.99 but greater than $25.30, a number of shares of common stock having a value, based on the average VWAP, equal to $50.00; and
·       if the average VWAP is less than or equal to $25.30, then 1.9763 shares (a maximum of 38,636,665 shares).
If holders elect to settle the 2011 Purchase Contract prior to May 1, 2014, they will receive 1.6133 shares of PPL common stock, subject to antidilution adjustments and an early settlement upon a Fundamental Change. In addition to the maximum shares noted above, up to 1.2 million shares could be issued under make-whole provisions in the event of early settlement upon a Fundamental Change.
A holder's ownership interest in the 2019 Notes is pledged to PPL to secure the holder's obligation under the related 2011 Purchase Contract. If a holder of a 2011 Purchase Contract chooses at any time no longer to be a holder of the 2019 Notes, such holder's obligation under the 2011 Purchase Contract must be secured by a U.S. Treasury security.
Each 2011 Purchase Contract also requires PPL to make quarterly contract adjustment payments at a rate of 4.43% per year on the $50.00 stated amount of the 2011 Equity Unit. PPL has the option to defer these contract adjustment payments until the 2011 Purchase Contract settlement date. Deferred contract adjustment payments will accrue additional contract adjustment payments at the rate of 8.75% per year until paid. Until any deferred contract adjustment payments have been paid, PPL may not declare or pay any dividends or distributions on, or redeem, purchase or acquire or make a liquidation payment with respect to, any of its capital stock, subject to certain exceptions.
The 2019 Notes are fully and unconditionally guaranteed by PPL as to payment of principal and interest. The 2019 Notes initially bear interest at 4.32% and are not subject to redemption prior to May 2016. Beginning May 2016, PPL Capital Funding may, at its option, redeem the 2019 Notes, in whole but not in part, at any time, at par plus accrued and unpaid interest. The 2019 Notes are expected to be remarketed in 2014 into two tranches, such that neither tranche will have an aggregate principal amount of less than the lesser of $250 million and 50% of the aggregate principal amount of the 2019 Notes to be remarketed. One tranche will mature on or about the third anniversary of the settlement of the remarketing, and the other tranche will mature on or about the fifth anniversary of such settlement. Upon a successful remarketing, the interest rate on the 2019 Notes may be reset and the maturity of the tranches may be modified as necessary. In connection with a remarketing, PPL Capital Funding may elect with respect to each tranche, to extend or eliminate the early redemption date and/or calculate interest on the notes of a tranche on a fixed or floating rate basis. If the remarketing fails, holders of the 2019 Notes will have the right to put their notes to PPL Capital Funding on May 1, 2014 for an amount equal to the principal amount plus accrued interest. In January 2014, PPL Capital Funding elected to conduct an optional remarketing of the 2019 Notes that will occur between January 30, 2014 and April 15, 2014.
Prior to May 2016, PPL Capital Funding may elect at one or more times to defer interest payments on the 2019 Notes for one or more consecutive interest periods until the earlier of the third anniversary of the interest payment due date and May 2016. Deferred interest payments will accrue additional interest at a rate equal to the interest rate then applicable to the 2019 Notes. Until any deferred interest payments have been paid, PPL may not, subject to certain exceptions, (i) declare or pay any dividends or distributions on, or redeem, purchase or acquire or make a liquidation payment with respect to, any of its capital stock, (ii) make any payment of principal of, or interest or premium, if any, on, or repay, purchase or redeem any of its debt securities that upon liquidation ranks equal with, or junior in interest to, the subordinated guarantee of the 2019 Notes by PPL as of the date of issuance and (iii) make any payments regarding any guarantee by PPL of securities of any of its subsidiaries (other than PPL Capital Funding) if the guarantee ranks equal with, or junior in interest to, the 2019 Notes as of the date of their issuance.
In the financial statements, the proceeds from the sale of the 2011 Equity Units were allocated to the 2019 Notes and the 2011 Purchase Contracts, including the obligation to make contract adjustment payments, based on the underlying fair value of each instrument at the time of issuance. As a result, the 2019 Notes were recorded at $978 million, which approximated fair value, as long-term debt. At the time of issuance, the present value of the contract adjustment payments of $123 million was recorded to other liabilities representing the obligation to make contract adjustment payments, with an offsetting reduction to additional paid-in capital for the issuance of the 2011 Purchase Contracts, which approximated the fair value of each. The liability is being accreted through interest expense over the three-year term of the 2011 Purchase Contracts. The initial valuation of the contract adjustment payments is considered a non-cash transaction that was excluded from the Statement of Cash Flows in 2011. See Note 4 for EPS considerations related to the 2011 Purchase Contracts.
Legal Separateness (All Registrants)
The subsidiaries of PPL are separate legal entities. PPL's subsidiaries are not liable for the debts of PPL. Accordingly, creditors of PPL may not satisfy their debts from the assets of PPL's subsidiaries absent a specific contractual undertaking by a subsidiary to pay PPL's creditors or as required by applicable law or regulation. Similarly, PPL is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of PPL's subsidiaries may not satisfy their debts from the assets of PPL or its other subsidiaries absent a specific contractual undertaking by PPL or its other subsidiaries to pay the creditors or as required by applicable law or regulation.
Similarly, the subsidiaries of PPL Energy Supply, PPL Electric and LKE are each separate legal entities. These subsidiaries are not liable for the debts of PPL Energy Supply, PPL Electric and LKE. Accordingly, creditors of PPL Energy Supply, 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 Energy Supply, PPL Electric and LKE are not liable for the debts of their subsidiaries, nor are their subsidiaries liable for the debts of one another. Accordingly, creditors of these subsidiaries may not satisfy their debts from the assets of PPL Energy Supply, 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.
Distributions, Capital Contributions and Related Restrictions
(PPL)
In November 2013, PPL declared its quarterly common stock dividend, payable January 2, 2014, at 36.75 cents per share (equivalent to $1.47 per annum). In February 2014, PPL declared its quarterly common stock dividend, payable April 1, 2014, at 37.25 cents per share (equivalent to $1.49 per annum). Future dividends, declared at the discretion of the Board of Directors, will depend upon future earnings, cash flows, financial and legal requirements and other factors.
Neither PPL Capital Funding nor PPL may declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest payments on its 2007 Series A Junior Subordinated Notes due 2067 or 2013 Series B Junior Subordinated Notes due 2073. Subject to certain exceptions, PPL may not declare or pay any dividend or distribution on its capital stock until any deferred interest payments on its 4.32% Junior Subordinated Notes due 2019 have been paid and deferred contract adjustment payments on PPL's 2011 Purchase Contracts have been paid. At December 31, 2013, no payments were deferred on any series of junior subordinated notes or the 2011 Purchase Contracts.
(All Registrants except PPL Energy Supply)
PPL relies on dividends or loans from its subsidiaries to fund PPL's dividends to its common shareholders. The net assets of certain PPL subsidiaries are subject to legal restrictions. LKE primarily relies on dividends from its subsidiaries to fund its dividends to PPL. LG&E, KU and PPL Electric are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in capital account." The meaning of this limitation has never been clarified under the Federal Power Act. LG&E, KU and PPL Electric believe, however, that this statutory restriction, as applied to their circumstances, would not be construed or applied by the FERC to prohibit the payment from retained earnings of dividends that are not excessive and are for lawful and legitimate business purposes. In February 2012, LG&E and KU petitioned the FERC requesting authorization to pay dividends in the future based on retained earnings balances calculated without giving effect to the impact of purchase accounting adjustments for the acquisition of LKE by PPL. In May 2012, 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, 2013, net assets of $2.5 billion ($1.0 billion for LG&E and $1.5 billion for KU) were restricted for purposes of paying dividends to LKE, and net assets of $2.5 billion ($1.0 billion for LG&E and $1.5 billion for KU) were available for payment of dividends to LKE. LG&E and KU believe they will not be required to change their current dividend practices as a result of the foregoing requirement. In addition, under Virginia law, KU is prohibited from making loans to affiliates without the prior approval of the VSCC. There are no comparable statutes under Kentucky law applicable to LG&E and KU, or under Pennsylvania law applicable to PPL Electric. However, orders from the KPSC require LG&E and KU to obtain prior consent or approval before lending amounts to PPL.
(PPL)
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 except PPL)
The following distributions and capital contributions occurred in 2013:
				PPL Energy				PPL
				Supply				Electric			LKE				LG&E			KU
Dividends/distributions paid to parent/member				$	408			$	127		$	254			$	99		$	124
Capital contributions received from parent/member					1,577				205			243				86			157

Acquisitions_Development_and_D

Acquisitions, Development and Divestitures	12 Months Ended
	Dec. 31, 2013
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 the projects, sell, cancel or expand them, execute tolling agreements or pursue other options. Any resulting transactions may impact future financial results. See Note 9 for information on discontinued operations. See Note 10 for information on completed acquisitions.
	Development
	(PPL, LKE, LG&E and KU)
	Cane Run Unit 7 Construction
	In September 2011, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to build Cane Run Unit 7. In May 2012, the KPSC issued an order approving the request. LG&E will own a 22% undivided interest, and KU will own a 78% undivided interest in the new NGCC generating unit. A formal request for recovery of the costs associated with the construction was not included in the CPCN application but certain Cane Run Unit 7 construction work in progress has been included in base rates and the remaining capital costs are expected to be included in future rate proceedings. LG&E and KU commenced preliminary construction activities in the third quarter of 2012 and project construction is expected to be completed by May 2015. The project, which includes building a natural gas supply pipeline and related transmission projects, has an estimated cost of approximately $600 million.
	In conjunction with this construction and to meet new, more stringent EPA regulations with a 2015 compliance date, LG&E and KU anticipate retiring five older coal-fired electric generating units at the Cane Run and Green River plants, which have a combined summer capacity rating of 724 MW. In addition, KU retired a 12 MW unit at the Haefling plant in December 2013 and the remaining 71 MW unit at the Tyrone plant in February 2013. There were no significant gains or losses related to the 2013 retirements.
	Future Capacity Needs
	In January 2014, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to construct a NGCC unit at KU's Green River generating site (Green River Unit 5) and a solar generating facility at the E. W. Brown generating site. Subject to finalizing details, regulatory applications, permitting and construction schedules, Green River Unit 5 is expected to have approximately 700 MW of capacity at an estimated cost of $700 million and is planned to be operational in 2018. Green River Unit 5 will be jointly owned by LG&E and KU, with LG&E owning a 40% undivided interest and KU owning a 60% undivided interest. The solar generating facility is expected to have approximately 10 MW of capacity at an estimated cost of $36 million and is planned to be operational in 2016. The solar generating facility will be jointly owned by LG&E and KU, with LG&E owning a 36% undivided interest and KU owning a 64% undivided interest.
	(PPL and PPL Energy Supply)
	Hydroelectric Expansion Projects
	In 2009, in light of the availability of tax incentives and potential federal loan guarantees for renewable projects contained in the Economic Stimulus Package, PPL Energy Supply filed an application with the FERC to expand capacity at its Holtwood and Rainbow hydroelectric facilities, which the FERC approved. In the first quarter of 2013, the Rainbow hydroelectric redevelopment project in Great Falls, Montana, which increased total capacity to 63 MW, was placed in service. In the fourth quarter of 2013, the 125 MW Holtwood project was placed in service.
	PPL Energy Supply believes that the projects are eligible for either investment tax credits or Section 1603 Treasury grants. As of December 31, 2013, PPL Energy Supply had recognized investment tax credits for both projects and continued to evaluate the desirability of obtaining Treasury grants in lieu of the investment tax credits.
	As of December 31, 2013, PPL Energy Supply had recorded cumulative deferred investment tax credits of $60 million and $117 million for the Rainbow and Holtwood hydroelectric facilities. The credits reduced PPL Energy Supply's tax liability and are amortized over the life of the related assets.
	In January 2014, the U.S. Department of Treasury awarded $56 million for Specified Energy Property in Lieu of Tax Credits for the Rainbow project. PPL Energy Supply has accepted and will account for the receipt of the $56 million grant in 2014. PPL Energy Supply is required to recapture $60 million of investment tax credits previously recorded related to the Rainbow project as a result of the grant receipt. The accounting for the grant receipt and recapture of investment tax credits is not expected to have a significant impact on the financial statements in 2014.
	Bell Bend COLA
	In 2008, a PPL Energy Supply subsidiary, PPL Bell Bend, LLC (PPL Bell Bend) submitted a COLA to the NRC for the proposed Bell Bend nuclear generating unit (Bell Bend) to be built adjacent to the Susquehanna plant.
	In 2008, PPL Bell Bend submitted Parts I and II of an application for a federal loan guarantee for Bell Bend to the DOE. In February 2014, the DOE announced the first loan guarantee for a nuclear project in Georgia. Eight of the ten applicants that submitted Part II applications remain active in the DOE program; however, the DOE has stated that the $18.5 billion currently appropriated to support new nuclear projects would not likely be enough for more than three projects. PPL Bell Bend submits quarterly application updates for Bell Bend to the DOE to remain active in the loan guarantee application process.
	The NRC continues to review the COLA. PPL Bell Bend does not expect to complete the COLA review process with the NRC prior to 2016. PPL Bell Bend has made no decision to proceed with construction and expects that such decision will not be made for several years given the anticipated lengthy NRC license approval process. Additionally, PPL Bell Bend does not expect to proceed with construction absent favorable economics, a joint arrangement with other interested parties and a federal loan guarantee or other acceptable financing. PPL Bell Bend is currently authorized to spend up to $224 million on the COLA and other permitting costs necessary for construction, which is expected to be sufficient to fund the project through receipt of the license. At December 31, 2013 and December 31, 2012, $173 million and $154 million of costs, which includes capitalized interest, associated with the licensing application were capitalized and are included on the Balance Sheets in noncurrent "Other intangibles." PPL Bell Bend believes that the estimated fair value of the COLA currently exceeds the costs expected to be capitalized associated with the licensing application.
	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 identified 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 PPL 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.
	Construction activities have been underway on the 101-mile route in Pennsylvania since 2012. The line is expected to be completed before the peak summer demand period of 2015. At December 31, 2013, PPL Electric's estimated share of the project cost was $630 million. At December 31, 2013, $377 million of costs were capitalized and are included on the Balance Sheet primarily in "Construction work in progress."
	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 construction work in progress (CWIP) costs but denied the requested incentive for a 100 basis point adder to the return on equity. The order required a follow-up compliance filing from PPL Electric to ensure proper accounting treatment of AFUDC and CWIP for the project, which PPL Electric submitted to the FERC in March 2013 and the FERC subsequently approved in April 2013.
	In December 2012, PPL Electric submitted an application to the PUC requesting permission to site and construct the project. A number of parties protested the application, which was subsequently assigned to an Administrative Law Judge (ALJ). Evidentiary hearings were held in July 2013. In October 2013, the ALJ concluded that PPL met its burden on all issues, and recommended that the PUC approve the siting application, two zoning petitions, and the remaining eminent domain applications. On January 9, 2014, the PUC issued a Final Order approving the Application. No party has filed an appeal of the PUC's decision and the deadline for such appeals has passed. PPL Electric expects the project to be completed in 2017. At December 31, 2013, PPL Electric's estimated cost of the project was $335 million, most of which qualifies for the CWIP incentive treatment.
	Other (PPL and PPL Energy Supply)
	Montana Transactions
	In September 2013, PPL Montana executed a definitive agreement to sell to NorthWestern its hydroelectric generating facilities located in Montana with a generation capacity of 633 MW for $900 million in cash, subject to certain adjustments. The sale, which is not expected to close before the second half of 2014, includes 11 hydroelectric power facilities and related assets. The sale is subject to closing conditions, including receipt of regulatory approvals by the FERC and the Montana Public Service Commission and certain third-party consents. Due to the uncertainties related to certain of these conditions as of December 31, 2013, the sale did not meet the applicable accounting criteria for the assets and liabilities included in the transaction to be classified as held for sale on the balance sheet.
	To facilitate the sale, on December 20, 2013, PPL Montana terminated its operating lease arrangement related to partial interests in Units 1, 2 and 3 of the Colstrip coal-fired electric generating facility and acquired those interests, collectively, for $271 million. At lease termination, the existing lease-related assets on the balance sheet consisting primarily of prepaid rent and leasehold improvements were written-off and the acquired Colstrip assets were recorded at fair value as of the acquisition date. PPL and PPL Energy Supply recorded a charge of $697 million ($413 million after-tax) for the termination of the lease included in "Loss on lease termination" on the 2013 Statements of Income. The $271 million payment is reflected in "Cash Flows from Operating Activities" on the 2013 Statements of Cash Flow.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2013
Discontinued Operations [Line Items]	'
Discontinued Operations	'
	9. Discontinued Operations
	Sale of Certain Non-core Generation Facilities (PPL and PPL Energy Supply)
	In 2011, PPL Energy Supply subsidiaries completed the sale of their ownership interests in certain non-core generation facilities, which were included in the Supply segment, for $381 million. The transaction included the natural gas-fired facilities in Wallingford, Connecticut and University Park, Illinois and an equity interest in Safe Harbor Water Power Corporation, which owns a hydroelectric facility in Conestoga, Pennsylvania. There was no significant impact on earnings in 2011 from the operation of this business or as a result of the sale.
	Distribution of Membership Interest in PPL Global to Parent (PPL Energy Supply)
	In January 2011, PPL Energy Supply distributed its entire membership interest in PPL Global to its parent, PPL Energy Funding. The distribution was made based on the book value of the assets and liabilities of PPL Global with financial effect as of January 1, 2011, and no gains or losses were recognized on the distribution.
	The amount of cash and cash equivalents of PPL Global at the time of the distribution was reflected as a financing activity in the 2011 Statement of Cash Flows.
PPL Energy Supply LLC [Member]	'
Discontinued Operations [Line Items]	'
Discontinued Operations	'
	9. Discontinued Operations
	Sale of Certain Non-core Generation Facilities (PPL and PPL Energy Supply)
	In 2011, PPL Energy Supply subsidiaries completed the sale of their ownership interests in certain non-core generation facilities, which were included in the Supply segment, for $381 million. The transaction included the natural gas-fired facilities in Wallingford, Connecticut and University Park, Illinois and an equity interest in Safe Harbor Water Power Corporation, which owns a hydroelectric facility in Conestoga, Pennsylvania. There was no significant impact on earnings in 2011 from the operation of this business or as a result of the sale.
	Distribution of Membership Interest in PPL Global to Parent (PPL Energy Supply)
	In January 2011, PPL Energy Supply distributed its entire membership interest in PPL Global to its parent, PPL Energy Funding. The distribution was made based on the book value of the assets and liabilities of PPL Global with financial effect as of January 1, 2011, and no gains or losses were recognized on the distribution.
	The amount of cash and cash equivalents of PPL Global at the time of the distribution was reflected as a financing activity in the 2011 Statement of Cash Flows.

Business_Acquisitions

Business Acquisitions	12 Months Ended
	Dec. 31, 2013
Business Acquisition [Line Items]	'
Business Acquisitions	'
	10. Business Acquisitions
	Ironwood Acquisition (PPL and PPL Energy Supply)
	On April 13, 2012, an indirect, wholly owned subsidiary of PPL Energy Supply completed the acquisition of all of the equity interests of two subsidiaries of The AES Corporation, AES Ironwood, L.L.C. (subsequently renamed PPL Ironwood, LLC) and AES Prescott, L.L.C. (subsequently renamed PPL Prescott, LLC), which together own and operate, the Ironwood Facility. The Ironwood Facility began operation in 2001 and, since 2008, PPL EnergyPlus has supplied natural gas for the facility and received the facility's full electricity output and capacity value pursuant to a tolling agreement that expires in 2021. The acquisition provides PPL Energy Supply, through its subsidiaries, operational control of additional combined-cycle gas generation in PJM.
	The fair value of the consideration paid for this acquisition was as follows.
	Aggregate enterprise consideration		$	326
	Less: Fair value of long-term debt outstanding assumed through consolidation (a)			258
	Plus: Restricted cash debt service reserves			17
	Cash consideration paid for equity interests (including working capital adjustments)		$	85
	(a)       The long-term debt assumed through consolidation consisted of $226 million aggregate principal amount of 8.857% senior secured bonds to be fully repaid by December 31, 2025, plus $8 million of debt service reserve loans, and a $24 million fair value adjustment. See Note 7 for information on the February 2013 exchange of a portion of long-term debt assumed through consolidation.
	Purchase Price Allocation
	The following table summarizes the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed through consolidation, and the effective settlement of the tolling agreement through consolidation.
	PP&E		$	505
	Long-term debt (current and noncurrent) (a)			-258
	Tolling agreement (b)			-170
	Other net assets (a)			8
	Net identifiable assets acquired		$	85
	(a)       Represents non-cash activity excluded from the 2012 Statement of Cash Flows.
	(b)       Prior to the acquisition, PPL EnergyPlus had recorded primarily an intangible asset, which represented its rights to and the related accounting for the tolling agreement with PPL Ironwood, LLC. On the acquisition date, PPL Ironwood, LLC recorded a liability, recognized at fair value, for its obligation to PPL EnergyPlus. The tolling agreement assets of PPL EnergyPlus and the tolling agreement liability of PPL Ironwood, LLC eliminate in consolidation for PPL and PPL Energy Supply as a result of the acquisition, and therefore the agreement is considered effectively settled. The difference between the tolling agreement assets and liability resulted in an insignificant loss on the effective settlement of the agreement.
	Acquisition of WPD Midlands (PPL)
	On April 1, 2011, PPL, through its indirect, wholly owned subsidiary PPL WEM, completed its acquisition of all of the outstanding ordinary share capital of Central Networks East plc and Central Networks Limited, the sole owner of Central Networks West plc, together with certain other related assets and liabilities (collectively referred to as Central Networks and subsequently renamed WPD Midlands), from subsidiaries of E.ON AG. The consideration for the acquisition consisted of cash of $5.8 billion, including the repayment of $1.7 billion of affiliate indebtedness owed to subsidiaries of E.ON AG, and approximately $800 million of long-term debt assumed through consolidation. WPD Midlands operates two regulated distribution networks that serve 5 million end-users in the Midlands area of England. The acquisition increased the regulated portion of PPL's business and enhances rate-regulated growth opportunities as the regulated businesses make investments to improve infrastructure and customer reliability. Further, since the service territories of WPD (South Wales), WPD (South West) and WPD Midlands are contiguous, cost savings, efficiencies and other benefits have been achieved from the combined operations of these entities.
	The fair value of the consideration paid for this acquisition was as follows (in billions).
	Aggregate enterprise consideration		$	6.6
	Less: Fair value of long-term debt outstanding assumed through consolidation			0.8
	Total cash consideration paid			5.8
	Less: Funds used to repay pre-acquisition affiliate indebtedness			1.7
	Cash consideration paid for Central Networks' outstanding ordinary share capital		$	4.1
	The total cash consideration paid was primarily funded by borrowings under the 2011 Bridge Facility on the date of acquisition. Subsequently, PPL repaid those borrowings in 2011 using proceeds from the permanent financing, including issuances of common stock and 2011 Equity Units, as well as proceeds from the issuance of debt by PPL WEM, WPD (East Midlands) and WPD (West Midlands). See Note 7 for additional information.
	Purchase Price Allocation
	The following table summarizes (in billions) the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed.
	Current assets (a)		$	0.2
	PP&E			4.9
	Intangible assets			0.1
	Other noncurrent assets			0.1
	Current liabilities (b)			-0.4
	PPL WEM affiliate indebtedness			-1.7
	Long-term debt (current and noncurrent) (b)			-0.8
	Other noncurrent liabilities (b)			-0.7
	Net identifiable assets acquired			1.7
	Goodwill			2.4
	Net assets acquired		$	4.1
	(a)       Includes gross contractual amount of the accounts receivable acquired of $122 million, which approximates fair value.
	(b)       Represents non-cash activity excluded from the 2011 Statement of Cash Flows.
	The purchase price allocation resulted in goodwill of $2.4 billion that was assigned to the U.K. Regulated segment. The goodwill is attributable to the expected continued growth of a rate-regulated business with a defined service area operating under a constructive regulatory framework, expected cost savings, efficiencies and other benefits resulting from a contiguous service area with WPD (South West) and WPD (South Wales), as well as the ability to leverage WPD (South West)'s and WPD (South Wales)'s existing management team's high level of performance in capital cost efficiency, system reliability and customer service. The goodwill is not deductible for U.K. income tax purposes.
	Separation Benefits - U.K. Regulated Segment
	In connection with the 2011 acquisition, PPL completed a reorganization designed to transition WPD Midlands from a functional operating structure to a regional operating structure requiring a smaller combined support structure, reducing duplication and implementing more efficient procedures. As a result of the reorganization, 729 employees of WPD Midlands were terminated.
	The separation benefits, before income taxes, associated with the reorganization were as follows.
	Severance compensation		$	61
	Early retirement deficiency costs (ERDC) under applicable pension plans			46
	Outplacement services			1
	Total separation benefits		$	108
	In connection with the reorganization, WPD Midlands recorded $93 million of the total expected separation benefits in 2011, of which $48 million related to severance compensation and $45 million related to ERDC. WPD Midlands recorded an additional $15 million of total separation benefits in 2012, of which $13 million related to severance compensation and $2 million related to ERDC. The accrued severance compensation is reflected in "Other current liabilities" and the ERDC reduced "Other noncurrent assets" on the Balance Sheets. All separation benefits are included in "Other operation and maintenance" on the Statements of Income.
	The changes in the carrying amounts of accrued severance were as follows.
				2012		2011
	Accrued severance at beginning of period		$	21
	Severance compensation			13	$	48
	Severance paid			-34		-27
	Accrued severance at end of period		$		$	21
	In addition to the reorganization costs noted above, an additional $9 million was recorded in 2011 for ERDC payable under applicable pension plans and severance compensation for certain employees who separated from the WPD Midlands companies, but were not part of the reorganization. These separation benefits are also included in "Other operation and maintenance" on the Statement of Income.
	Other
	WPD Midlands 2011 financial results included in PPL's Statement of Income and included in the U.K. Regulated segment were as follows.
	Operating Revenues				$	790
	Net Income Attributable to PPL Shareowners					137
	Pro forma Information
The pro forma financial information, which includes WPD Midlands as if the acquisition had occurred January 1, 2010, is as follows.
						2011
Operating Revenues - PPL consolidated pro forma (unaudited)						$	13,140
Net Income Attributable to PPL Shareowners - PPL consolidated pro forma (unaudited)							1,800
The pro forma financial information presented above has been derived from the historical combined financial statements of WPD Midlands, which was acquired on April 1, 2011. Income (loss) from discontinued operations (net of income taxes), which was not significant for 2011, was excluded from the pro forma amounts above.
The pro forma financial information presented above includes adjustments to depreciation, net periodic pension costs, interest expense and the related income tax effects to reflect the impact of the acquisition. The pre-tax nonrecurring credits (expenses) presented in the following table were directly attributable to the acquisition and adjustments were included in the calculation of pro forma operating revenue and net income to remove the effect of these nonrecurring items and the related income tax effects.
			Income Statement
			Line Item					2011
WPD Midlands acquisition
	2011 Bridge Facility costs (a)		Interest Expense					$	-44
	Foreign currency loss on 2011 Bridge Facility (b)		Other Income (Expense) - net						-57
	Net hedge gains associated with the 2011 Bridge Facility (c)		Other Income (Expense) - net						55
	Hedge ineffectiveness (d)		Interest Expense						-12
	U.K. stamp duty tax (e)		Other Income (Expense) - net						-21
	Separation benefits (f)		Other operation and maintenance						-102
	Other acquisition-related adjustments		(g)						-77
(a)       The 2011 Bridge Facility costs, primarily commitment and structuring fees, were incurred to establish a bridge facility for purposes of funding the WPD Midlands acquisition purchase price.
(b)       The 2011 Bridge Facility was denominated in GBP. The amount includes a $42 million foreign currency loss on PPL Capital Funding's repayment of its 2011 Bridge Facility borrowing and a $15 million foreign currency loss associated with proceeds received on the U.S. dollar-denominated senior notes issued by PPL WEM in April 2011 that were used to repay a portion of PPL WEM's borrowing under the 2011 Bridge Facility.
(c)       The repayment of borrowings on the 2011 Bridge Facility was economically hedged to mitigate the effects of changes in foreign currency exchange rates with forward contracts to purchase GBP, which resulted in net hedge gains.
(d)       The hedge ineffectiveness includes a combination of ineffectiveness associated with closed out interest rate swaps and a charge recorded as a result of certain interest rate swaps failing hedge effectiveness testing, both associated with the acquisition financing.
(e)       The U.K. stamp duty tax represents a tax on the transfer of ownership of property in the U.K. incurred in connection with the acquisition.
(f)       See "Separation Benefits - U.K. Regulated Segment" above.
(g)       Primarily includes acquisition-related advisory, accounting and legal fees recorded in "Other Income (Expense) - net" and contract termination costs, rebranding costs and relocation costs recorded in "Other operation and maintenance."
PPL Energy Supply LLC [Member]	'
Business Acquisition [Line Items]	'
Business Acquisitions	'
	10. Business Acquisitions
	Ironwood Acquisition (PPL and PPL Energy Supply)
	On April 13, 2012, an indirect, wholly owned subsidiary of PPL Energy Supply completed the acquisition of all of the equity interests of two subsidiaries of The AES Corporation, AES Ironwood, L.L.C. (subsequently renamed PPL Ironwood, LLC) and AES Prescott, L.L.C. (subsequently renamed PPL Prescott, LLC), which together own and operate, the Ironwood Facility. The Ironwood Facility began operation in 2001 and, since 2008, PPL EnergyPlus has supplied natural gas for the facility and received the facility's full electricity output and capacity value pursuant to a tolling agreement that expires in 2021. The acquisition provides PPL Energy Supply, through its subsidiaries, operational control of additional combined-cycle gas generation in PJM.
	The fair value of the consideration paid for this acquisition was as follows.
	Aggregate enterprise consideration		$	326
	Less: Fair value of long-term debt outstanding assumed through consolidation (a)			258
	Plus: Restricted cash debt service reserves			17
	Cash consideration paid for equity interests (including working capital adjustments)		$	85
	(a)       The long-term debt assumed through consolidation consisted of $226 million aggregate principal amount of 8.857% senior secured bonds to be fully repaid by December 31, 2025, plus $8 million of debt service reserve loans, and a $24 million fair value adjustment. See Note 7 for information on the February 2013 exchange of a portion of long-term debt assumed through consolidation.
	Purchase Price Allocation
	The following table summarizes the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed through consolidation, and the effective settlement of the tolling agreement through consolidation.
	PP&E		$	505
	Long-term debt (current and noncurrent) (a)			-258
	Tolling agreement (b)			-170
	Other net assets (a)			8
	Net identifiable assets acquired		$	85
	(a)       Represents non-cash activity excluded from the 2012 Statement of Cash Flows.
	(b)       Prior to the acquisition, PPL EnergyPlus had recorded primarily an intangible asset, which represented its rights to and the related accounting for the tolling agreement with PPL Ironwood, LLC. On the acquisition date, PPL Ironwood, LLC recorded a liability, recognized at fair value, for its obligation to PPL EnergyPlus. The tolling agreement assets of PPL EnergyPlus and the tolling agreement liability of PPL Ironwood, LLC eliminate in consolidation for PPL and PPL Energy Supply as a result of the acquisition, and therefore the agreement is considered effectively settled. The difference between the tolling agreement assets and liability resulted in an insignificant loss on the effective settlement of the agreement.
	Acquisition of WPD Midlands (PPL)
	On April 1, 2011, PPL, through its indirect, wholly owned subsidiary PPL WEM, completed its acquisition of all of the outstanding ordinary share capital of Central Networks East plc and Central Networks Limited, the sole owner of Central Networks West plc, together with certain other related assets and liabilities (collectively referred to as Central Networks and subsequently renamed WPD Midlands), from subsidiaries of E.ON AG. The consideration for the acquisition consisted of cash of $5.8 billion, including the repayment of $1.7 billion of affiliate indebtedness owed to subsidiaries of E.ON AG, and approximately $800 million of long-term debt assumed through consolidation. WPD Midlands operates two regulated distribution networks that serve 5 million end-users in the Midlands area of England. The acquisition increased the regulated portion of PPL's business and enhances rate-regulated growth opportunities as the regulated businesses make investments to improve infrastructure and customer reliability. Further, since the service territories of WPD (South Wales), WPD (South West) and WPD Midlands are contiguous, cost savings, efficiencies and other benefits have been achieved from the combined operations of these entities.
	The fair value of the consideration paid for this acquisition was as follows (in billions).
	Aggregate enterprise consideration		$	6.6
	Less: Fair value of long-term debt outstanding assumed through consolidation			0.8
	Total cash consideration paid			5.8
	Less: Funds used to repay pre-acquisition affiliate indebtedness			1.7
	Cash consideration paid for Central Networks' outstanding ordinary share capital		$	4.1
	The total cash consideration paid was primarily funded by borrowings under the 2011 Bridge Facility on the date of acquisition. Subsequently, PPL repaid those borrowings in 2011 using proceeds from the permanent financing, including issuances of common stock and 2011 Equity Units, as well as proceeds from the issuance of debt by PPL WEM, WPD (East Midlands) and WPD (West Midlands). See Note 7 for additional information.
	Purchase Price Allocation
	The following table summarizes (in billions) the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed.
	Current assets (a)		$	0.2
	PP&E			4.9
	Intangible assets			0.1
	Other noncurrent assets			0.1
	Current liabilities (b)			-0.4
	PPL WEM affiliate indebtedness			-1.7
	Long-term debt (current and noncurrent) (b)			-0.8
	Other noncurrent liabilities (b)			-0.7
	Net identifiable assets acquired			1.7
	Goodwill			2.4
	Net assets acquired		$	4.1
	(a)       Includes gross contractual amount of the accounts receivable acquired of $122 million, which approximates fair value.
	(b)       Represents non-cash activity excluded from the 2011 Statement of Cash Flows.
	The purchase price allocation resulted in goodwill of $2.4 billion that was assigned to the U.K. Regulated segment. The goodwill is attributable to the expected continued growth of a rate-regulated business with a defined service area operating under a constructive regulatory framework, expected cost savings, efficiencies and other benefits resulting from a contiguous service area with WPD (South West) and WPD (South Wales), as well as the ability to leverage WPD (South West)'s and WPD (South Wales)'s existing management team's high level of performance in capital cost efficiency, system reliability and customer service. The goodwill is not deductible for U.K. income tax purposes.
	Separation Benefits - U.K. Regulated Segment
	In connection with the 2011 acquisition, PPL completed a reorganization designed to transition WPD Midlands from a functional operating structure to a regional operating structure requiring a smaller combined support structure, reducing duplication and implementing more efficient procedures. As a result of the reorganization, 729 employees of WPD Midlands were terminated.
	The separation benefits, before income taxes, associated with the reorganization were as follows.
	Severance compensation		$	61
	Early retirement deficiency costs (ERDC) under applicable pension plans			46
	Outplacement services			1
	Total separation benefits		$	108
	In connection with the reorganization, WPD Midlands recorded $93 million of the total expected separation benefits in 2011, of which $48 million related to severance compensation and $45 million related to ERDC. WPD Midlands recorded an additional $15 million of total separation benefits in 2012, of which $13 million related to severance compensation and $2 million related to ERDC. The accrued severance compensation is reflected in "Other current liabilities" and the ERDC reduced "Other noncurrent assets" on the Balance Sheets. All separation benefits are included in "Other operation and maintenance" on the Statements of Income.
	The changes in the carrying amounts of accrued severance were as follows.
				2012		2011
	Accrued severance at beginning of period		$	21
	Severance compensation			13	$	48
	Severance paid			-34		-27
	Accrued severance at end of period		$		$	21
	In addition to the reorganization costs noted above, an additional $9 million was recorded in 2011 for ERDC payable under applicable pension plans and severance compensation for certain employees who separated from the WPD Midlands companies, but were not part of the reorganization. These separation benefits are also included in "Other operation and maintenance" on the Statement of Income.
	Other
	WPD Midlands 2011 financial results included in PPL's Statement of Income and included in the U.K. Regulated segment were as follows.
	Operating Revenues				$	790
	Net Income Attributable to PPL Shareowners					137
	Pro forma Information
The pro forma financial information, which includes WPD Midlands as if the acquisition had occurred January 1, 2010, is as follows.
						2011
Operating Revenues - PPL consolidated pro forma (unaudited)						$	13,140
Net Income Attributable to PPL Shareowners - PPL consolidated pro forma (unaudited)							1,800
The pro forma financial information presented above has been derived from the historical combined financial statements of WPD Midlands, which was acquired on April 1, 2011. Income (loss) from discontinued operations (net of income taxes), which was not significant for 2011, was excluded from the pro forma amounts above.
The pro forma financial information presented above includes adjustments to depreciation, net periodic pension costs, interest expense and the related income tax effects to reflect the impact of the acquisition. The pre-tax nonrecurring credits (expenses) presented in the following table were directly attributable to the acquisition and adjustments were included in the calculation of pro forma operating revenue and net income to remove the effect of these nonrecurring items and the related income tax effects.
			Income Statement
			Line Item					2011
WPD Midlands acquisition
	2011 Bridge Facility costs (a)		Interest Expense					$	-44
	Foreign currency loss on 2011 Bridge Facility (b)		Other Income (Expense) - net						-57
	Net hedge gains associated with the 2011 Bridge Facility (c)		Other Income (Expense) - net						55
	Hedge ineffectiveness (d)		Interest Expense						-12
	U.K. stamp duty tax (e)		Other Income (Expense) - net						-21
	Separation benefits (f)		Other operation and maintenance						-102
	Other acquisition-related adjustments		(g)						-77
(a)       The 2011 Bridge Facility costs, primarily commitment and structuring fees, were incurred to establish a bridge facility for purposes of funding the WPD Midlands acquisition purchase price.
(b)       The 2011 Bridge Facility was denominated in GBP. The amount includes a $42 million foreign currency loss on PPL Capital Funding's repayment of its 2011 Bridge Facility borrowing and a $15 million foreign currency loss associated with proceeds received on the U.S. dollar-denominated senior notes issued by PPL WEM in April 2011 that were used to repay a portion of PPL WEM's borrowing under the 2011 Bridge Facility.
(c)       The repayment of borrowings on the 2011 Bridge Facility was economically hedged to mitigate the effects of changes in foreign currency exchange rates with forward contracts to purchase GBP, which resulted in net hedge gains.
(d)       The hedge ineffectiveness includes a combination of ineffectiveness associated with closed out interest rate swaps and a charge recorded as a result of certain interest rate swaps failing hedge effectiveness testing, both associated with the acquisition financing.
(e)       The U.K. stamp duty tax represents a tax on the transfer of ownership of property in the U.K. incurred in connection with the acquisition.
(f)       See "Separation Benefits - U.K. Regulated Segment" above.
(g)       Primarily includes acquisition-related advisory, accounting and legal fees recorded in "Other Income (Expense) - net" and contract termination costs, rebranding costs and relocation costs recorded in "Other operation and maintenance."

Leases

Leases	12 Months Ended
	Dec. 31, 2013
Leases [Line Items]	'
Leases	'
	11. Leases
	Lessee Transactions
	(PPL and PPL Energy Supply)
	Kerr Dam
	Under the Kerr Hydroelectric Project No. 5 joint operating license issued by the FERC, PPL Montana is responsible to make payments to the Confederated Salish and Kootenai Tribes of the Flathead Nation for the use of certain of their tribal lands in connection with the operation of Kerr Dam. This payment arrangement, subject to escalation based upon inflation, extends until the end of the license term in 2035. Between 2015 and 2025, the tribes have the option to purchase, hold and operate the project, at a conveyance price to be determined in accordance with the provisions in the FERC license. Exercise of the option by the tribes would result in the termination of this payment arrangement obligation for PPL Montana. The payment arrangement has been treated as an operating lease for accounting purposes. In February 2013, the parties to the license submitted the issue of the appropriate amount of the conveyance price to arbitration. Arbitration was held before an American Arbitration Association panel in January 2014, and a decision is to be issued on or before March 5, 2014.  On January 29, 2014, the arbitration panel issued a partial award of tangible asset portions of the conveyance price in the amount of $17 million to PPL Montana, reserving decision on the proposed inclusion of approximately $32 million of environmental mitigation costs until a final award is made in March.
	(All registrants except PPL Electric)
	Other Leases
	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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
PPL Energy Supply LLC [Member]	'
Leases [Line Items]	'
Leases	'
	11. Leases
	Lessee Transactions
	(PPL and PPL Energy Supply)
	Kerr Dam
	Under the Kerr Hydroelectric Project No. 5 joint operating license issued by the FERC, PPL Montana is responsible to make payments to the Confederated Salish and Kootenai Tribes of the Flathead Nation for the use of certain of their tribal lands in connection with the operation of Kerr Dam. This payment arrangement, subject to escalation based upon inflation, extends until the end of the license term in 2035. Between 2015 and 2025, the tribes have the option to purchase, hold and operate the project, at a conveyance price to be determined in accordance with the provisions in the FERC license. Exercise of the option by the tribes would result in the termination of this payment arrangement obligation for PPL Montana. The payment arrangement has been treated as an operating lease for accounting purposes. In February 2013, the parties to the license submitted the issue of the appropriate amount of the conveyance price to arbitration. Arbitration was held before an American Arbitration Association panel in January 2014, and a decision is to be issued on or before March 5, 2014.  On January 29, 2014, the arbitration panel issued a partial award of tangible asset portions of the conveyance price in the amount of $17 million to PPL Montana, reserving decision on the proposed inclusion of approximately $32 million of environmental mitigation costs until a final award is made in March.
	(All registrants except PPL Electric)
	Other Leases
	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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
LG And E And KU Energy LLC [Member]	'
Leases [Line Items]	'
Leases	'
	11. Leases
	Lessee Transactions
	(PPL and PPL Energy Supply)
	Kerr Dam
	Under the Kerr Hydroelectric Project No. 5 joint operating license issued by the FERC, PPL Montana is responsible to make payments to the Confederated Salish and Kootenai Tribes of the Flathead Nation for the use of certain of their tribal lands in connection with the operation of Kerr Dam. This payment arrangement, subject to escalation based upon inflation, extends until the end of the license term in 2035. Between 2015 and 2025, the tribes have the option to purchase, hold and operate the project, at a conveyance price to be determined in accordance with the provisions in the FERC license. Exercise of the option by the tribes would result in the termination of this payment arrangement obligation for PPL Montana. The payment arrangement has been treated as an operating lease for accounting purposes. In February 2013, the parties to the license submitted the issue of the appropriate amount of the conveyance price to arbitration. Arbitration was held before an American Arbitration Association panel in January 2014, and a decision is to be issued on or before March 5, 2014.  On January 29, 2014, the arbitration panel issued a partial award of tangible asset portions of the conveyance price in the amount of $17 million to PPL Montana, reserving decision on the proposed inclusion of approximately $32 million of environmental mitigation costs until a final award is made in March.
	(All registrants except PPL Electric)
	Other Leases
	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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
Louisville Gas And Electric Co [Member]	'
Leases [Line Items]	'
Leases	'
	11. Leases
	Lessee Transactions
	(PPL and PPL Energy Supply)
	Kerr Dam
	Under the Kerr Hydroelectric Project No. 5 joint operating license issued by the FERC, PPL Montana is responsible to make payments to the Confederated Salish and Kootenai Tribes of the Flathead Nation for the use of certain of their tribal lands in connection with the operation of Kerr Dam. This payment arrangement, subject to escalation based upon inflation, extends until the end of the license term in 2035. Between 2015 and 2025, the tribes have the option to purchase, hold and operate the project, at a conveyance price to be determined in accordance with the provisions in the FERC license. Exercise of the option by the tribes would result in the termination of this payment arrangement obligation for PPL Montana. The payment arrangement has been treated as an operating lease for accounting purposes. In February 2013, the parties to the license submitted the issue of the appropriate amount of the conveyance price to arbitration. Arbitration was held before an American Arbitration Association panel in January 2014, and a decision is to be issued on or before March 5, 2014.  On January 29, 2014, the arbitration panel issued a partial award of tangible asset portions of the conveyance price in the amount of $17 million to PPL Montana, reserving decision on the proposed inclusion of approximately $32 million of environmental mitigation costs until a final award is made in March.
	(All registrants except PPL Electric)
	Other Leases
	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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
Kentucky Utilities Co [Member]	'
Leases [Line Items]	'
Leases	'
	11. Leases
	Lessee Transactions
	(PPL and PPL Energy Supply)
	Kerr Dam
	Under the Kerr Hydroelectric Project No. 5 joint operating license issued by the FERC, PPL Montana is responsible to make payments to the Confederated Salish and Kootenai Tribes of the Flathead Nation for the use of certain of their tribal lands in connection with the operation of Kerr Dam. This payment arrangement, subject to escalation based upon inflation, extends until the end of the license term in 2035. Between 2015 and 2025, the tribes have the option to purchase, hold and operate the project, at a conveyance price to be determined in accordance with the provisions in the FERC license. Exercise of the option by the tribes would result in the termination of this payment arrangement obligation for PPL Montana. The payment arrangement has been treated as an operating lease for accounting purposes. In February 2013, the parties to the license submitted the issue of the appropriate amount of the conveyance price to arbitration. Arbitration was held before an American Arbitration Association panel in January 2014, and a decision is to be issued on or before March 5, 2014.  On January 29, 2014, the arbitration panel issued a partial award of tangible asset portions of the conveyance price in the amount of $17 million to PPL Montana, reserving decision on the proposed inclusion of approximately $32 million of environmental mitigation costs until a final award is made in March.
	(All registrants except PPL Electric)
	Other Leases
	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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2013
Stock-Based Compensation [Line Items]	'
Stock-Based Compensation	'
	12. Stock-Based Compensation
	(All Registrants except LG&E and KU)
	In 2012, shareowners approved the PPL SIP. This new equity plan replaces the PPL ICP and incorporates 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 of 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 stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units would be deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICP and 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, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Energy Supply, 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 awards 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 delivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws.
	Restricted Stock 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 reaches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The shares are subject to forfeiture or accelerated payout under plan provisions for termination, retirement, disability and death of employees. Restricted shares vest fully, in certain situations, as defined by each of the Plans.
	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 vesting period, generally three years.
	The fair value of restricted stock and restricted stock units granted is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units 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 and restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restricted stock and restricted stock units vest fully, in certain situations, as defined by each of the Plans.
	The weighted-average grant date fair value of restricted stock and restricted stock units granted was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
	Substantially all restricted stock and restricted stock unit awards are expected to vest.
	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was:
				2013		2012			2011
PPL			$	19	$	27		$	19
PPL Energy Supply				7		6			6
PPL Electric				3		2			2
LKE				1		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 an index group, in the case of the 2011 awards, the S&P 500 Electric Utilities Index, and in the case of the 2012 and 2013 awards, the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each 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 threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, 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. The fair value of performance units granted is recognized as compensation expense on a straight-line basis over the three-year performance period. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans.
The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands.
The weighted-average assumptions used in the model were:
				2013		2012			2011
Risk-free interest rate				0.36%		0.30%			1.00%
Expected stock volatility				15.50%		19.30%			23.40%
Expected life				3 years		3 years			3 years
The weighted-average grant date fair value of performance units granted was:
			2013		2012			2011
PPL			$	34.15	$	31.41		$	29.67
PPL Energy Supply				34.29		31.4			29.68
PPL Electric				33.97		31.37			29.57
LKE				33.84		31.3			29.2
Performance unit activity for 2013 was:
					Weighted-
					Average Grant
			Performance		Date Fair Value
			Units		Per Share
PPL
Nonvested, beginning of period				594,203	$	31.14
	Granted			348,495		34.15
	Forfeited			-149,499		32.63
Nonvested, end of period				793,199		32.19
PPL Energy Supply
Nonvested, beginning of period				124,189	$	31.26
	Granted			74,614		34.29
	Forfeited			-28,194		33.47
Nonvested, end of period				170,609		32.22
PPL Electric
Nonvested, beginning of period				26,083	$	31.1
	Granted			18,666		33.97
	Forfeited			-6,539		32.78
Nonvested, end of period				38,210		32.22
LKE
Nonvested, beginning of period				82,750	$	30.62
	Granted			49,540		33.84
	Forfeited			-2,660		29.17
Nonvested, end of period				129,630		31.88
Stock Options
Under the Plans, stock options may be 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, 2013, 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 which 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 over 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 volatility, 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. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands. The dividend yield is based on several factors, 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		2012			2011
Risk-free interest rate				1.15%		1.13%			2.34%
Expected option life				6.48 years		6.17 years			5.71 years
Expected stock volatility				18.50%		20.60%			21.60%
Dividend yield				5.00%		5.00%			5.93%
The weighted-average grant date fair value of options granted was:
			2013		2012			2011
PPL			$	2.18	$	2.48		$	2.47
PPL Energy Supply				2.19		2.51			2.47
PPL Electric				2.19		2.5			2.47
LKE				2.18		2.51			2.47
Stock option activity for 2013 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				9,134,545	$	30.36
	Granted			3,383,630		29.56
	Exercised			-1,136,693		27.13
Outstanding at end of period				11,381,482		30.45			6.6		$	15
Options exercisable at end of period				6,415,615		31.66			5			8
PPL Energy Supply
Outstanding at beginning of period				2,265,123	$	30.45
	Transferred			88,546		25.67
	Granted			713,030		29.66
	Exercised			-221,363		25.76
Outstanding at end of period				2,845,336		30.47			6.2		$	4
Options exercisable at end of period				1,747,842		31.48			4.6			2
PPL Electric
Outstanding at beginning of period				340,530	$	30.35
	Granted			191,670		29.49
Outstanding at end of period				532,200		30.04			7.1		$	1
Options exercisable at end of period				260,950		31.24			5.5
LKE
Outstanding at beginning of period				634,847	$	27.11
	Granted			501,950		29.51
	Exercised			-139,641		26.87
Outstanding at end of period				997,156		28.35			8.4		$	2
Options exercisable at end of period				250,682		27.22			7.7			1
PPL received $31 million in cash from stock options exercised in 2013. The related tax savings were not significant for 2013. Substantially all stock option awards are expected to vest.
The total intrinsic value of stock options exercised for 2013 was $6 million and was not significant for 2012 and 2011.
Compensation Expense
Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was as follows:
			2013		2012			2011
PPL			$	52	$	49		$	36
PPL Energy Supply				27		23			16
PPL Electric				10		11			8
LKE				8		8			5
The income tax benefit related to above compensation expense was as follows:
			2013		2012			2011
PPL			$	22	$	20		$	15
PPL Energy Supply				11		10			6
PPL Electric				4		4			3
LKE				3		4			2
The income tax benefit PPL realized from stock-based awards vested or exercised for 2013 was not significant.
At December 31, 2013, 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			$	33		1.9 years
PPL Energy Supply				13		2.0 years
PPL Electric				3		2.0 years
LKE				2		1.7 years
PPL Energy Supply LLC [Member]	'
Stock-Based Compensation [Line Items]	'
Stock-Based Compensation	'
	12. Stock-Based Compensation
	(All Registrants except LG&E and KU)
	In 2012, shareowners approved the PPL SIP. This new equity plan replaces the PPL ICP and incorporates 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 of 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 stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units would be deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICP and 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, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Energy Supply, 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 awards 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 delivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws.
	Restricted Stock 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 reaches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The shares are subject to forfeiture or accelerated payout under plan provisions for termination, retirement, disability and death of employees. Restricted shares vest fully, in certain situations, as defined by each of the Plans.
	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 vesting period, generally three years.
	The fair value of restricted stock and restricted stock units granted is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units 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 and restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restricted stock and restricted stock units vest fully, in certain situations, as defined by each of the Plans.
	The weighted-average grant date fair value of restricted stock and restricted stock units granted was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
	Substantially all restricted stock and restricted stock unit awards are expected to vest.
	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was:
				2013		2012			2011
PPL			$	19	$	27		$	19
PPL Energy Supply				7		6			6
PPL Electric				3		2			2
LKE				1		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 an index group, in the case of the 2011 awards, the S&P 500 Electric Utilities Index, and in the case of the 2012 and 2013 awards, the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each 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 threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, 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. The fair value of performance units granted is recognized as compensation expense on a straight-line basis over the three-year performance period. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans.
The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands.
The weighted-average assumptions used in the model were:
				2013		2012			2011
Risk-free interest rate				0.36%		0.30%			1.00%
Expected stock volatility				15.50%		19.30%			23.40%
Expected life				3 years		3 years			3 years
The weighted-average grant date fair value of performance units granted was:
			2013		2012			2011
PPL			$	34.15	$	31.41		$	29.67
PPL Energy Supply				34.29		31.4			29.68
PPL Electric				33.97		31.37			29.57
LKE				33.84		31.3			29.2
Performance unit activity for 2013 was:
					Weighted-
					Average Grant
			Performance		Date Fair Value
			Units		Per Share
PPL
Nonvested, beginning of period				594,203	$	31.14
	Granted			348,495		34.15
	Forfeited			-149,499		32.63
Nonvested, end of period				793,199		32.19
PPL Energy Supply
Nonvested, beginning of period				124,189	$	31.26
	Granted			74,614		34.29
	Forfeited			-28,194		33.47
Nonvested, end of period				170,609		32.22
PPL Electric
Nonvested, beginning of period				26,083	$	31.1
	Granted			18,666		33.97
	Forfeited			-6,539		32.78
Nonvested, end of period				38,210		32.22
LKE
Nonvested, beginning of period				82,750	$	30.62
	Granted			49,540		33.84
	Forfeited			-2,660		29.17
Nonvested, end of period				129,630		31.88
Stock Options
Under the Plans, stock options may be 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, 2013, 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 which 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 over 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 volatility, 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. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands. The dividend yield is based on several factors, 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		2012			2011
Risk-free interest rate				1.15%		1.13%			2.34%
Expected option life				6.48 years		6.17 years			5.71 years
Expected stock volatility				18.50%		20.60%			21.60%
Dividend yield				5.00%		5.00%			5.93%
The weighted-average grant date fair value of options granted was:
			2013		2012			2011
PPL			$	2.18	$	2.48		$	2.47
PPL Energy Supply				2.19		2.51			2.47
PPL Electric				2.19		2.5			2.47
LKE				2.18		2.51			2.47
Stock option activity for 2013 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				9,134,545	$	30.36
	Granted			3,383,630		29.56
	Exercised			-1,136,693		27.13
Outstanding at end of period				11,381,482		30.45			6.6		$	15
Options exercisable at end of period				6,415,615		31.66			5			8
PPL Energy Supply
Outstanding at beginning of period				2,265,123	$	30.45
	Transferred			88,546		25.67
	Granted			713,030		29.66
	Exercised			-221,363		25.76
Outstanding at end of period				2,845,336		30.47			6.2		$	4
Options exercisable at end of period				1,747,842		31.48			4.6			2
PPL Electric
Outstanding at beginning of period				340,530	$	30.35
	Granted			191,670		29.49
Outstanding at end of period				532,200		30.04			7.1		$	1
Options exercisable at end of period				260,950		31.24			5.5
LKE
Outstanding at beginning of period				634,847	$	27.11
	Granted			501,950		29.51
	Exercised			-139,641		26.87
Outstanding at end of period				997,156		28.35			8.4		$	2
Options exercisable at end of period				250,682		27.22			7.7			1
PPL received $31 million in cash from stock options exercised in 2013. The related tax savings were not significant for 2013. Substantially all stock option awards are expected to vest.
The total intrinsic value of stock options exercised for 2013 was $6 million and was not significant for 2012 and 2011.
Compensation Expense
Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was as follows:
			2013		2012			2011
PPL			$	52	$	49		$	36
PPL Energy Supply				27		23			16
PPL Electric				10		11			8
LKE				8		8			5
The income tax benefit related to above compensation expense was as follows:
			2013		2012			2011
PPL			$	22	$	20		$	15
PPL Energy Supply				11		10			6
PPL Electric				4		4			3
LKE				3		4			2
The income tax benefit PPL realized from stock-based awards vested or exercised for 2013 was not significant.
At December 31, 2013, 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			$	33		1.9 years
PPL Energy Supply				13		2.0 years
PPL Electric				3		2.0 years
LKE				2		1.7 years
PPL Electric Utilities Corp [Member]	'
Stock-Based Compensation [Line Items]	'
Stock-Based Compensation	'
	12. Stock-Based Compensation
	(All Registrants except LG&E and KU)
	In 2012, shareowners approved the PPL SIP. This new equity plan replaces the PPL ICP and incorporates 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 of 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 stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units would be deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICP and 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, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Energy Supply, 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 awards 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 delivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws.
	Restricted Stock 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 reaches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The shares are subject to forfeiture or accelerated payout under plan provisions for termination, retirement, disability and death of employees. Restricted shares vest fully, in certain situations, as defined by each of the Plans.
	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 vesting period, generally three years.
	The fair value of restricted stock and restricted stock units granted is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units 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 and restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restricted stock and restricted stock units vest fully, in certain situations, as defined by each of the Plans.
	The weighted-average grant date fair value of restricted stock and restricted stock units granted was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
	Substantially all restricted stock and restricted stock unit awards are expected to vest.
	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was:
				2013		2012			2011
PPL			$	19	$	27		$	19
PPL Energy Supply				7		6			6
PPL Electric				3		2			2
LKE				1		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 an index group, in the case of the 2011 awards, the S&P 500 Electric Utilities Index, and in the case of the 2012 and 2013 awards, the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each 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 threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, 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. The fair value of performance units granted is recognized as compensation expense on a straight-line basis over the three-year performance period. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans.
The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands.
The weighted-average assumptions used in the model were:
				2013		2012			2011
Risk-free interest rate				0.36%		0.30%			1.00%
Expected stock volatility				15.50%		19.30%			23.40%
Expected life				3 years		3 years			3 years
The weighted-average grant date fair value of performance units granted was:
			2013		2012			2011
PPL			$	34.15	$	31.41		$	29.67
PPL Energy Supply				34.29		31.4			29.68
PPL Electric				33.97		31.37			29.57
LKE				33.84		31.3			29.2
Performance unit activity for 2013 was:
					Weighted-
					Average Grant
			Performance		Date Fair Value
			Units		Per Share
PPL
Nonvested, beginning of period				594,203	$	31.14
	Granted			348,495		34.15
	Forfeited			-149,499		32.63
Nonvested, end of period				793,199		32.19
PPL Energy Supply
Nonvested, beginning of period				124,189	$	31.26
	Granted			74,614		34.29
	Forfeited			-28,194		33.47
Nonvested, end of period				170,609		32.22
PPL Electric
Nonvested, beginning of period				26,083	$	31.1
	Granted			18,666		33.97
	Forfeited			-6,539		32.78
Nonvested, end of period				38,210		32.22
LKE
Nonvested, beginning of period				82,750	$	30.62
	Granted			49,540		33.84
	Forfeited			-2,660		29.17
Nonvested, end of period				129,630		31.88
Stock Options
Under the Plans, stock options may be 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, 2013, 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 which 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 over 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 volatility, 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. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands. The dividend yield is based on several factors, 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		2012			2011
Risk-free interest rate				1.15%		1.13%			2.34%
Expected option life				6.48 years		6.17 years			5.71 years
Expected stock volatility				18.50%		20.60%			21.60%
Dividend yield				5.00%		5.00%			5.93%
The weighted-average grant date fair value of options granted was:
			2013		2012			2011
PPL			$	2.18	$	2.48		$	2.47
PPL Energy Supply				2.19		2.51			2.47
PPL Electric				2.19		2.5			2.47
LKE				2.18		2.51			2.47
Stock option activity for 2013 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				9,134,545	$	30.36
	Granted			3,383,630		29.56
	Exercised			-1,136,693		27.13
Outstanding at end of period				11,381,482		30.45			6.6		$	15
Options exercisable at end of period				6,415,615		31.66			5			8
PPL Energy Supply
Outstanding at beginning of period				2,265,123	$	30.45
	Transferred			88,546		25.67
	Granted			713,030		29.66
	Exercised			-221,363		25.76
Outstanding at end of period				2,845,336		30.47			6.2		$	4
Options exercisable at end of period				1,747,842		31.48			4.6			2
PPL Electric
Outstanding at beginning of period				340,530	$	30.35
	Granted			191,670		29.49
Outstanding at end of period				532,200		30.04			7.1		$	1
Options exercisable at end of period				260,950		31.24			5.5
LKE
Outstanding at beginning of period				634,847	$	27.11
	Granted			501,950		29.51
	Exercised			-139,641		26.87
Outstanding at end of period				997,156		28.35			8.4		$	2
Options exercisable at end of period				250,682		27.22			7.7			1
PPL received $31 million in cash from stock options exercised in 2013. The related tax savings were not significant for 2013. Substantially all stock option awards are expected to vest.
The total intrinsic value of stock options exercised for 2013 was $6 million and was not significant for 2012 and 2011.
Compensation Expense
Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was as follows:
			2013		2012			2011
PPL			$	52	$	49		$	36
PPL Energy Supply				27		23			16
PPL Electric				10		11			8
LKE				8		8			5
The income tax benefit related to above compensation expense was as follows:
			2013		2012			2011
PPL			$	22	$	20		$	15
PPL Energy Supply				11		10			6
PPL Electric				4		4			3
LKE				3		4			2
The income tax benefit PPL realized from stock-based awards vested or exercised for 2013 was not significant.
At December 31, 2013, 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			$	33		1.9 years
PPL Energy Supply				13		2.0 years
PPL Electric				3		2.0 years
LKE				2		1.7 years
LG And E And KU Energy LLC [Member]	'
Stock-Based Compensation [Line Items]	'
Stock-Based Compensation	'
	12. Stock-Based Compensation
	(All Registrants except LG&E and KU)
	In 2012, shareowners approved the PPL SIP. This new equity plan replaces the PPL ICP and incorporates 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 of 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 stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units would be deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICP and 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, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Energy Supply, 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 awards 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 delivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws.
	Restricted Stock 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 reaches a certain age or meets service or other criteria set forth in the executive's restricted stock award agreement. The shares are subject to forfeiture or accelerated payout under plan provisions for termination, retirement, disability and death of employees. Restricted shares vest fully, in certain situations, as defined by each of the Plans.
	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 vesting period, generally three years.
	The fair value of restricted stock and restricted stock units granted is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock and restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units 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 and restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restricted stock and restricted stock units vest fully, in certain situations, as defined by each of the Plans.
	The weighted-average grant date fair value of restricted stock and restricted stock units granted was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
	Substantially all restricted stock and restricted stock unit awards are expected to vest.
	The total fair value of restricted stock and restricted stock units vesting for the years ended December 31 was:
				2013		2012			2011
PPL			$	19	$	27		$	19
PPL Energy Supply				7		6			6
PPL Electric				3		2			2
LKE				1		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 an index group, in the case of the 2011 awards, the S&P 500 Electric Utilities Index, and in the case of the 2012 and 2013 awards, the Philadelphia Stock Exchange Utility Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each 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 threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the determination of the CGNC of whether the performance goals have been achieved. Under the plan provisions, 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. The fair value of performance units granted is recognized as compensation expense on a straight-line basis over the three-year performance period. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans.
The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands.
The weighted-average assumptions used in the model were:
				2013		2012			2011
Risk-free interest rate				0.36%		0.30%			1.00%
Expected stock volatility				15.50%		19.30%			23.40%
Expected life				3 years		3 years			3 years
The weighted-average grant date fair value of performance units granted was:
			2013		2012			2011
PPL			$	34.15	$	31.41		$	29.67
PPL Energy Supply				34.29		31.4			29.68
PPL Electric				33.97		31.37			29.57
LKE				33.84		31.3			29.2
Performance unit activity for 2013 was:
					Weighted-
					Average Grant
			Performance		Date Fair Value
			Units		Per Share
PPL
Nonvested, beginning of period				594,203	$	31.14
	Granted			348,495		34.15
	Forfeited			-149,499		32.63
Nonvested, end of period				793,199		32.19
PPL Energy Supply
Nonvested, beginning of period				124,189	$	31.26
	Granted			74,614		34.29
	Forfeited			-28,194		33.47
Nonvested, end of period				170,609		32.22
PPL Electric
Nonvested, beginning of period				26,083	$	31.1
	Granted			18,666		33.97
	Forfeited			-6,539		32.78
Nonvested, end of period				38,210		32.22
LKE
Nonvested, beginning of period				82,750	$	30.62
	Granted			49,540		33.84
	Forfeited			-2,660		29.17
Nonvested, end of period				129,630		31.88
Stock Options
Under the Plans, stock options may be 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, 2013, 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 which 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 over 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 volatility, 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. Beginning in 2011, PPL began using a mix of historic and implied volatility in response to the significant changes in its business model, moving from a primarily unregulated to a primarily regulated business model, as a result of the acquisitions of LKE and WPD Midlands. The dividend yield is based on several factors, 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		2012			2011
Risk-free interest rate				1.15%		1.13%			2.34%
Expected option life				6.48 years		6.17 years			5.71 years
Expected stock volatility				18.50%		20.60%			21.60%
Dividend yield				5.00%		5.00%			5.93%
The weighted-average grant date fair value of options granted was:
			2013		2012			2011
PPL			$	2.18	$	2.48		$	2.47
PPL Energy Supply				2.19		2.51			2.47
PPL Electric				2.19		2.5			2.47
LKE				2.18		2.51			2.47
Stock option activity for 2013 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				9,134,545	$	30.36
	Granted			3,383,630		29.56
	Exercised			-1,136,693		27.13
Outstanding at end of period				11,381,482		30.45			6.6		$	15
Options exercisable at end of period				6,415,615		31.66			5			8
PPL Energy Supply
Outstanding at beginning of period				2,265,123	$	30.45
	Transferred			88,546		25.67
	Granted			713,030		29.66
	Exercised			-221,363		25.76
Outstanding at end of period				2,845,336		30.47			6.2		$	4
Options exercisable at end of period				1,747,842		31.48			4.6			2
PPL Electric
Outstanding at beginning of period				340,530	$	30.35
	Granted			191,670		29.49
Outstanding at end of period				532,200		30.04			7.1		$	1
Options exercisable at end of period				260,950		31.24			5.5
LKE
Outstanding at beginning of period				634,847	$	27.11
	Granted			501,950		29.51
	Exercised			-139,641		26.87
Outstanding at end of period				997,156		28.35			8.4		$	2
Options exercisable at end of period				250,682		27.22			7.7			1
PPL received $31 million in cash from stock options exercised in 2013. The related tax savings were not significant for 2013. Substantially all stock option awards are expected to vest.
The total intrinsic value of stock options exercised for 2013 was $6 million and was not significant for 2012 and 2011.
Compensation Expense
Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was as follows:
			2013		2012			2011
PPL			$	52	$	49		$	36
PPL Energy Supply				27		23			16
PPL Electric				10		11			8
LKE				8		8			5
The income tax benefit related to above compensation expense was as follows:
			2013		2012			2011
PPL			$	22	$	20		$	15
PPL Energy Supply				11		10			6
PPL Electric				4		4			3
LKE				3		4			2
The income tax benefit PPL realized from stock-based awards vested or exercised for 2013 was not significant.
At December 31, 2013, 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			$	33		1.9 years
PPL Energy Supply				13		2.0 years
PPL Electric				3		2.0 years
LKE				2		1.7 years

Retirement_and_Postemployment_

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2013
Retirement and Postemployment Benefits [Abstract]	'
Retirement and Postemployment Benefits	'
	13. Retirement and Postemployment Benefits
	(All Registrants)
	Defined Benefits
	The majority of PPL's subsidiaries domestic employees 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 domestic qualified pension plans were closed to newly hired salaried employees. Newly hired bargaining unit employees continue to be eligible under the plans based on their collective bargaining agreements. Salaried employees hired on or after January 1, 2012 are eligible to participate in the PPL Retirement Savings Plan, a 401(k) savings plan with enhanced employer matching.
	The majority of PPL Montana employees are eligible for pension benefits under a cash balance pension plan. Effective January 1, 2012, that plan was closed to newly hired salaried employees. Eligibility of newly hired bargaining unit employees under the plan is based on their collective bargaining agreements. Salaried employees hired on or after January 1, 2012 are eligible to participate in the PPL Retirement Savings Plan.
	The defined benefit pension plans of LKE and its subsidiaries were closed to new salaried and bargaining unit employees hired after December 31, 2005. Employees hired after December 31, 2005 receive additional company contributions above the standard matching contributions to their savings plans.
	Employees of certain of PPL Energy Supply's mechanical contracting companies are eligible for benefits under multiemployer plans sponsored by various unions.
	Effective April 1, 2010, PPL WW's principal defined benefit pension plan was closed to most new employees, except for those meeting specific grandfathered participation rights. WPD Midlands was acquired by PPL WEM on April 1, 2011. WPD Midlands' defined benefit plan had been closed to new members, except for those meeting specific grandfathered participation rights, prior to acquisition. New employees not eligible to participate in the plans are offered benefits under a defined contribution plan.
	PPL and certain of its subsidiaries also provide supplemental retirement benefits to executives and other key management employees through unfunded nonqualified retirement plans.
	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 to newly hired salaried employees. Postretirement health benefits may be paid from 401(h) accounts established as part of the PPL Retirement Plan and the LG&E and KU Retirement Plan within the PPL Services Corporation Master Trust, funded VEBA trusts and company funds. Postretirement benefits under the PPL Montana Retiree Health Plan are paid from company assets. 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 (U.K.) pension and other postretirement benefit plans for the years ended December 31.
					Pension Benefits
					U.S.									U.K.									Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011			2013			2012			2011
	Net periodic defined benefit costs
		(credits):
	Service cost				$	126		$	103		$	95		$	69		$	54		$	44		$	14		$	12		$	12
	Interest cost					213			220			217			320			340			282			29			31			33
	Expected return on plan assets					-293			-259			-245			-465			-458			-338			-25			-23			-23
	Amortization of:
			Transition (asset) obligation																								2			2
			Prior service cost (credit)			22			24			24			1			4			4						1
			Actuarial (gain) loss			80			42			30			150			79			57			6			4			6
	Net periodic defined benefit costs
		(credits) prior to settlement
		charges and termination benefits				148			130			121			75			19			49			24			27			30
	Settlement charges								11
	Termination benefits (a)														3			2			50
	Net periodic defined benefit costs
		(credits)			$	148		$	141		$	121		$	78		$	21		$	99		$	24		$	27		$	30
	Other Changes in Plan Assets
		and Benefit Obligations
		Recognized in OCI and
		Regulatory Assets/Liabilities -
		Gross:
	Settlements							$	-11
	Net (gain) loss				$	-319			372		$	117		$	76		$	1,073		$	152		$	-68		$	13		$	-9
	Prior service cost
		(credit)										8												-3			-1			10
	Amortization of:
			Transition asset (obligation)																								-2			-2
			Prior service (cost) credit			-22			-24			-24			-1			-4			-4						-1
			Actuarial gain (loss)			-80			-42			-30			-150			-79			-57			-6			-4			-6
	Total recognized in OCI and
		regulatory assets/liabilities (b)				-421			295			71			-75			990			91			-77			5			-7
	Total recognized in net periodic
		defined benefit costs, OCI and
		regulatory assets/liabilities (b)			$	-273		$	436		$	192		$	3		$	1,011		$	190		$	-53		$	32		$	23
	(a)       Related to the WPD Midlands separations in the U.K.
	(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 recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows:
				U.S. Pension Benefits										Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011
	OCI			$	-228		$	181		$	47		$	-41		$	12		$	-6
	Regulatory assets/liabilities				-193			114			24			-36			-7			-1
	Total recognized in OCI and
		regulatory assets/liabilities		$	-421		$	295		$	71		$	-77		$	5		$	-7
	The estimated amounts to be amortized from AOCI and regulatory assets/liabilities into net periodic defined benefit costs in 2014 are as follows:
			Pension Benefits
			U.S.			U.K.
	Prior service cost (credit)		$	20
	Actuarial (gain) loss			30		$	131
Total		$	50		$	131
Amortization from Balance Sheet:
AOCI		$	22		$	131
Regulatory assets/liabilities			28
Total		$	50		$	131
(PPL Energy Supply)
The following table provides the components of net periodic defined benefit costs for PPL Energy Supply's pension and other postretirement benefit plans for the years ended December 31.
				Pension Benefits									Other Postretirement Benefits
				2013			2012			2011			2013			2012			2011
Net periodic defined benefit costs
(credits):
Service cost				$	7		$	6		$	5		$	1		$	1		$	1
Interest cost					8			7			7						1			1
Expected return on plan assets					-10			-9			-9
Amortization of:
		Actuarial (gain) loss			3			2			2
Net periodic defined benefit costs
	(credits)			$	8		$	6		$	5		$	1		$	2		$	2
Other Changes in Plan Assets
	and Benefit Obligations
	Recognized in OCI:
Net (gain) loss				$	-15		$	16		$	7		$	-1					$	-2
Prior service cost (credit)														-3		$	-1
Amortization of:
		Actuarial gain (loss)			-3			-2			-2
Total recognized in OCI					-18			14			5			-4			-1			-2
Total recognized in net periodic
	defined benefit costs and OCI			$	-10		$	20		$	10		$	-3		$	1		$
Actuarial loss of $2 million related to PPL Energy Supply's pension plan is expected to be amortized from AOCI into net periodic defined benefit costs in 2014.
(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
				2013			2012			2011			2013			2012			2011
Net periodic defined benefit costs
	(credits):
Service cost				$	26		$	22		$	24		$	5		$	4		$	4
Interest cost					62			64			67			8			9			10
Expected return on plan assets					-82			-70			-64			-5			-4			-3
Amortization of:
		Transition (asset) obligation															2			2
		Prior service cost (credit)			5			5			5			3			3			2
		Actuarial (gain) loss			33			22			24						-1
Net periodic defined benefit costs (credits)				$	44		$	43		$	56		$	11		$	13		$	15
Other Changes in Plan Assets
	and Benefit Obligations
	Recognized in OCI and
	Regulatory Assets/Liabilities -
	Gross:
Net (gain) loss				$	-116		$	96		$	29		$	-14		$	-11		$	-3
Prior service cost (credit)											8									11
Amortization of:
		Transition (asset) obligation															-2			-2
		Prior service (cost) credit			-5			-5			-5			-3			-3			-2
		Actuarial gain (loss)			-33			-22			-24						1
Total recognized in OCI and
	regulatory assets/liabilities				-154			69			8			-17			-15			4
Total recognized in net periodic
	defined benefit costs, OCI and regulatory
	assets/liabilities			$	-110		$	112		$	64		$	-6		$	-2		$	19
For LKE's pension and other postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows:
				Pension Benefits									Other Postretirement Benefits
				2013			2012			2011			2013			2012			2011
	OCI			$	-46		$	34		$	1		$	-1		$	-1		$	2
	Regulatory assets/liabilities				-108			35			7			-16			-14			2
	Total recognized in OCI and
		regulatory assets/liabilities		$	-154		$	69		$	8		$	-17		$	-15		$	4
The estimated amounts to be amortized from regulatory assets/liabilities into net periodic defined benefit costs for LKE in 2014 are as follows.
					Other
		Pension			Postretirement
		Benefits			Benefits
Prior service cost (credit)		$	5		$	2
Actuarial (gain) loss			13			-1
Total		$	18		$	1
Amortization from Balance Sheet:
Regulatory assets/liabilities		$	18		$	1
Total		$	18		$	1
(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
				2013			2012			2011
Net periodic defined benefit costs (credits):
Service cost				$	2		$	2		$	2
Interest cost					14			14			14
Expected return on plan assets					-20			-19			-18
Amortization of:
		Prior service cost (credit)			2			3			2
		Actuarial (gain) loss			14			11			11
Net periodic defined benefit costs (credits)				$	12		$	11		$	11
Other Changes in Plan Assets and Benefit Obligations
	Recognized in Regulatory Assets - Gross:
Net (gain) loss				$	-20		$	18		$	15
Prior service cost (credit)											9
Amortization of:
		Prior service (cost) credit			-2			-2			-2
		Actuarial gain (loss)			-14			-11			-11
Total recognized in regulatory assets/liabilities					-36			5			11
Total recognized in net periodic defined benefit costs and regulatory assets				$	-24		$	16		$	22
The estimated amounts to be amortized from regulatory assets into net periodic defined benefit costs for LG&E in 2014 are as follows.
		Pension
		Benefits
Prior service cost (credit)		$	2
Actuarial (gain) loss			6
Total		$	8
(All Registrants)
The following net periodic defined benefit costs (credits) were charged to operating expense, 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
		2013			2012			2011			2013			2012			2011			2013			2012			2011
PPL		$	117		$	119		$	98		$	33		$	25		$	82		$	19		$	22		$	24
PPL Energy Supply			45			37			27												6			6			7
PPL Electric (a)			18			19			14												3			3			4
LKE			32			31			40												8			9			11
LG&E			14			13			16												4			5			5
KU (a)			9			8			10												2			3			4
(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.
In the table above, for PPL Energy Supply and LG&E, amounts include costs for the specific plans each sponsors and the following allocated costs of defined benefit plans sponsored by PPL Services (for PPL Energy Supply) and by LKE (for LG&E), based on their participation in those plans, which management believes are reasonable:
				Pension Benefits										Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011
PPL Energy Supply				$	38		$	31		$	23		$	5		$	5		$	6
LG&E			5			5			7			4			5			5
(All Registrants except PPL Electric and KU)
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
			2013			2012			2013			2012			2013			2012
PPL
	Discount rate			5.12%			4.22%			4.41%			4.27%			4.91%			4.00%
	Rate of compensation increase			3.97%			3.98%			4.00%			4.00%			3.96%			3.97%
PPL Energy Supply
	Discount rate			5.18%			4.25%									4.51%			3.77%
	Rate of compensation increase			3.94%			3.95%									3.94%			3.95%
LKE
	Discount rate			5.18%			4.24%									4.91%			3.99%
	Rate of compensation increase			4.00%			4.00%									4.00%			4.00%
LG&E
	Discount rate			5.13%			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
			2013			2012			2011			2013			2012			2011			2013			2012			2011
PPL
	Discount rate			4.22%			5.06%			5.42%			4.27%			5.24%			5.59%			4.00%			4.80%			5.14%
	Rate of compensation increase			3.98%			4.02%			4.88%			4.00%			4.00%			3.75%			3.97%			4.00%			4.90%
	Expected return on plan assets (a)			7.03%			7.07%			7.25%			7.16%			7.17%			7.04%			5.94%			5.99%			6.57%
PPL Energy Supply
	Discount rate			4.25%			5.12%			5.47%												3.77%			4.60%			4.95%
	Rate of compensation increase			3.95%			4.00%			4.75%												3.95%			4.00%			4.75%
	Expected return on plan assets (a)			7.00%			7.00%			7.25%												N/A			N/A			N/A
LKE
	Discount rate			4.24%			5.09%			5.49%												3.99%			4.78%			5.12%
	Rate of compensation increase			4.00%			4.00%			5.25%												4.00%			4.00%			5.25%
	Expected return on plan assets (a)			7.10%			7.25%			7.25%												6.76%			7.02%			7.16%
LG&E
	Discount rate			4.20%			5.00%			5.39%
	Expected return on plan assets (a)			7.10%			7.25%			7.25%
					2013			2012			2011
PPL and PPL Energy Supply
	Health care cost trend rate assumed for next year
			- obligations			7.60%			8.00%			8.50%
			- cost			8.00%			8.50%			9.00%
	Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
			- obligations			5.00%			5.50%			5.50%
			- cost			5.50%			5.50%			5.50%
	Year that the rate reaches the ultimate trend rate
			- obligations			2020			2019			2019
			- cost			2019			2019			2019
LKE
	Health care cost trend rate assumed for next year
			- obligations			7.60%			8.00%			8.50%
			- cost			8.00%			8.50%			9.00%
	Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
			- obligations			5.00%			5.50%			5.50%
			- cost			5.50%			5.50%			5.50%
	Year that the rate reaches the ultimate trend rate
			- obligations			2020			2019			2019
			- cost			2019			2019			2019
A one percentage point change in the assumed health care costs trend rate assumption would have had the following effects on the other postretirement benefit plans in 2013:
			One Percentage Point
			Increase			Decrease
Effect on accumulated postretirement benefit obligation
	PPL		$	6		$	-5
	LKE			5			-4
The effects on PPL Energy Supply's other postretirement benefit plan would not have been significant.
(PPL)
The funded status of PPL's plans at December 31 was as follows:
				Pension Benefits
				U.S.						U.K.						Other Postretirement Benefits
				2013			2012			2013			2012			2013			2012
Change in Benefit Obligation
Benefit Obligation, beginning of period				$	5,046		$	4,381		$	7,888		$	6,638		$	722		$	687
		Service cost			126			103			69			54			14			12
		Interest cost			213			220			320			340			29			31
		Participant contributions									15			15			12			6
		Plan amendments															-4			-1
		Actuarial (gain) loss			-540			546			46			1,081			-54			31
		Settlements						-25
		Termination benefits									3			2
		Net transfer in (out)												12
		Actual expenses paid						-3
		Gross benefits paid (a)			-254			-176			-375			-397			-57			-46
		Federal subsidy																		2
		Currency conversion									177			143
Benefit Obligation, end of period					4,591			5,046			8,143			7,888			662			722
Change in Plan Assets
Plan assets at fair value, beginning of period					3,939			3,471			6,911			6,351			421			391
		Actual return on plan assets			72			432			438			476			37			42
		Employer contributions			399			239			134			341			30			27
		Participant contributions									15			15			12			5
		Settlements						-25
		Actual expenses paid						-2
		Gross benefits paid (a)			-254			-176			-375			-397			-54			-44
		Currency conversion									161			125
Plan assets at fair value, end of period					4,156			3,939			7,284			6,911			446			421
Funded Status, end of period				$	-435		$	-1,107		$	-859		$	-977		$	-216		$	-301
Amounts recognized in the Balance
	Sheets consist of:
		Current liability		$	-8		$	-8								$	-1		$	-1
		Noncurrent liability			-427			-1,099		$	-859		$	-977			-215			-300
Net amount recognized, end of period				$	-435		$	-1,107		$	-859		$	-977		$	-216		$	-301
Amounts recognized in AOCI and
	regulatory assets/liabilities (pre-tax)
	consist of:
Prior service cost (credit)				$	69		$	91					$	1		$	-11		$	-7
Net actuarial (gain) loss					842			1,241		$	2,112			2,184			33			106
Total (b)				$	911		$	1,332		$	2,112		$	2,185		$	22		$	99
Total accumulated benefit obligation
	for defined benefit pension plans			$	4,191		$	4,569		$	7,542		$	7,259
(a)       Certain U.S. pension plans offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump sum payment. The increase in gross benefits paid is primarily the result of $64 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with these offerings.
(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 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
			2013			2012			2013			2012
AOCI			$	430		$	659		$	19		$	59
Regulatory assets/liabilities				481			673			3			40
Total			$	911		$	1,332		$	22		$	99
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
			2013			2012			2013			2012
Projected benefit obligation		$	4,591		$	5,046		$	8,143		$	7,888
Fair value of plan assets			4,156			3,939			7,284			6,911
		U.S.						U.K.
		ABO in excess of plan assets						ABO in excess of plan assets
			2013			2012			2013			2012
Accumulated benefit obligation		$	572		$	4,569		$	3,441		$	3,349
Fair value of plan assets			431			3,939			3,131			2,812
(PPL Energy Supply)
The funded status of PPL Energy Supply's plans at December 31 was as follows:
				Pension Benefits
				U.S.						Other Postretirement Benefits
				2013			2012			2013			2012
Change in Benefit Obligation
Benefit Obligation, beginning of period				$	176		$	143		$	17		$	17
		Service cost			7			6			1			1
		Interest cost			8			7						1
		Plan amendments									-4			-1
		Actuarial (gain) loss			-23			23			-1
		Gross benefits paid			-5			-3			-1			-1
Benefit Obligation, end of period					163			176			12			17
Change in Plan Assets
Plan assets at fair value, beginning of
	period				149			132
		Actual return on plan assets			3			16
		Employer contributions						4			1
		Gross benefits paid			-5			-3			-1
Plan assets at fair value, end of period					147			149
Funded Status, end of period				$	-16		$	-27		$	-12		$	-17
Amounts recognized in the Balance
	Sheets consist of:
		Current liability								$	-1		$	-1
		Noncurrent liability		$	-16		$	-27			-11			-16
Net amount recognized, end of period				$	-16		$	-27		$	-12		$	-17
Amounts recognized in AOCI
	(pre-tax) consist of:
Prior service cost (credit)										$	-5		$	-1
Net actuarial (gain) loss				$	34		$	52			1			2
Total				$	34		$	52		$	-4		$	1
Total accumulated benefit obligation
	for defined benefit pension plans			$	163		$	176
PPL Energy Supply's pension plan had projected and accumulated benefit obligations in excess of the fair value of plan assets at December 31, 2013 and 2012.
In addition to the plans it sponsors, PPL Energy Supply and its subsidiaries are allocated a portion of the funded status and costs of the defined benefit plans sponsored by PPL Services based on their participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to PPL Energy Supply resulted in liabilities at December 31 as follows:
		2013			2012
Pension		$	96		$	268
Other postretirement benefits			35			60
(LKE)
The funded status of LKE's plans at December 31 was as follows:
				Pension Benefits						Other Postretirement Benefits
				2013			2012			2013			2012
Change in Benefit Obligation
Benefit Obligation, beginning of period				$	1,487		$	1,306		$	209		$	214
		Service cost			26			22			5			4
		Interest cost			62			63			8			9
		Participant contributions									7			8
		Actuarial (gain) loss			-177			144			-18			-8
		Gross benefits paid (a)			-70			-48			-18			-19
		Federal subsidy												1
Benefit Obligation, end of period					1,328			1,487			193			209
Change in Plan Assets
Plan assets at fair value, beginning of period					1,070			944			68			58
		Actual return on plan assets			21			117			1			8
		Employer contributions			152			57			16			13
		Participant contributions									7			8
		Gross benefits paid (a)			-70			-48			-18			-19
Plan assets at fair value, end of period					1,173			1,070			74			68
Funded Status, end of period				$	-155		$	-417		$	-119		$	-141
Amounts recognized in the Balance
	Sheets consist of:
		Current liability		$	-3		$	-3
		Noncurrent liability			-152			-414		$	-119		$	-141
Net amount recognized, end of period				$	-155		$	-417		$	-119		$	-141
Amounts recognized in AOCI and
	regulatory assets/liabilities (pre-tax)
	consist of:
Prior service cost (credit)				$	24		$	28		$	8		$	11
Net actuarial (gain) loss					205			355			-30			-17
Total				$	229		$	383		$	-22		$	-6
Total accumulated benefit obligation
	for defined benefit pension plans			$	1,176		$	1,319
(a)       Certain LKE pension plans offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The increase in gross benefits paid is primarily the result of $21 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with these offerings.
The amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows:
			Pension Benefits						Other Postretirement Benefits
			2013			2012			2013			2012
	AOCI		$	-19		$	27
	Regulatory assets/liabilities			248			356		$	-22		$	-6
	Total		$	229		$	383		$	-22		$	-6
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:
		PBO in excess of plan assets
			2013			2012
Projected benefit obligation		$	1,328		$	1,487
Fair value of plan assets			1,173			1,070
		ABO in excess of plan assets
			2013			2012
Accumulated benefit obligation		$	350		$	1,319
Fair value of plan assets			284			1,070
(LG&E)
The funded status of LG&E's plan at December 31, was as follows:
								Pension Benefits
								2013			2012
Change in Benefit Obligation
Benefit Obligation, beginning of period								$	331		$	298
		Service cost							2			1
		Interest cost							14			14
		Actuarial (gain) loss							-35			32
		Gross benefits paid (a)							-21			-14
Benefit Obligation, end of period									291			331
Change in Plan Assets
Plan assets at fair value, beginning of period									287			256
		Actual return on plan assets							4			32
		Employer contributions							11			13
		Gross benefits paid (a)							-21			-14
Plan assets at fair value, end of period									281			287
Funded Status, end of period								$	-10		$	-44
Amounts recognized in the Balance Sheets consist of:
		Noncurrent liability						$	-10		$	-44
Net amount recognized, end of period								$	-10		$	-44
Amounts recognized in regulatory assets (pre-tax)
	consist of:
Prior service cost (credit)								$	15		$	17
Net actuarial (gain) loss									90			123
Total								$	105		$	140
Total accumulated benefit obligation for defined benefit pension plan								$	288		$	328
(a)       LG&E's pension plan offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The increase in gross benefits paid is primarily the result of $7 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with this offering.
LG&E's pension plan had projected and accumulated benefit obligations in excess of plan assets at December 31, 2013 and 2012.
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 actuarially determined obligations of current active employees and retired employees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to LG&E resulted in liabilities at December 31 as follows:
		2013			2012
Pension		$	9		$	58
Other postretirement benefits			73			81
(PPL and PPL Energy Supply)
PPL Energy Supply's mechanical contracting subsidiaries make contributions to over 70 multiemployer pension plans, based on the bargaining units from which labor is procured. The risks of participating in these multiemployer plans are different from single-employer plans in the following aspects:
       Assets contributed to the multiemployer plan by one employer may be used to provide benefits to employees of other participating employers.
       If a participating employer stops contributing to the plan, the unfunded obligations of the plan may be borne by the remaining participating employers.
       If PPL Energy Supply's mechanical contracting subsidiaries choose to stop participating in some of their multiemployer plans, they may be required to pay those plans an amount based on the unfunded status of the plan, referred to as a withdrawal liability.
PPL Energy Supply identified the Steamfitters Local Union No. 420 Pension Plan, EIN/Plan Number 23-2004424/001 as the only significant plan to which contributions are made. Contributions to this plan by PPL Energy Supply's mechanical contracting companies were $5 million for 2013, 2012 and 2011. At the date the financial statements were issued, the Form 5500 was not available for the plan year ending in 2013. Therefore, the following disclosures specific to this plan are being made based on the Form 5500s filed for the plan years ended December 31, 2012 and 2011. PPL Energy Supply's mechanical contracting subsidiaries were not identified individually as greater than 5% contributors on the Form 5500s. However, the combined contributions of the three subsidiaries contributing to the plan had exceeded 5%. The plan had a Pension Protection Act zone status of red and yellow, without utilizing an extended amortization period, as of December 31, 2012 and 2011. In addition, the plan is subject to a rehabilitation plan and surcharges have been applied to participating employer contributions. The expiration date of the collective-bargaining agreement related to those employees participating in this plan is April 30, 2014. There were no other plans deemed individually significant based on a multifaceted assessment of each plan. This assessment included review of the funded/zone status of each plan and PPL Energy Supply's potential obligations under the plan and the number of participating employers contributing to the plan.
PPL Energy Supply's mechanical contracting subsidiaries also participate in multiemployer other postretirement plans that provide for retiree life insurance and health benefits.
The table below details total contributions to all multiemployer pension and other postretirement plans, including the plan identified as significant above. The contribution amounts fluctuate each year based on the volume of work and type of projects undertaken from year to year.
		2013			2012			2011
Pension Plans		$	36		$	31		$	36
Other Postretirement Benefit Plans			32			28			31
Total Contributions		$	68		$	59		$	67
(PPL Electric)
Although PPL Electric does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by PPL Services based on its participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to PPL Electric resulted in liabilities at December 31 as follows.
		2013			2012
Pension		$	96		$	237
Other postretirement benefits			41			61
(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.
		2013			2012
Pension		$	11		$	104
Other postretirement benefits			42			53
Plan Assets - U.S. Pension Plans
(All Registrants except PPL Electric and KU)
PPL's primary legacy pension plan, the pension plans sponsored by LKE and the pension plan in which employees of PPL Montana participate are invested in the PPL Services Corporation Master Trust (the Master Trust) that also includes 401(h) accounts that are restricted for certain other postretirement benefit obligations of PPL and LKE. The investment strategy for the Master Trust is to achieve a risk-adjusted return on a mix of assets that, in combination with PPL's funding policy, will ensure that sufficient assets are available to provide long-term growth and liquidity for benefit payments, while also managing the duration of the assets to complement the duration of the liabilities. The Master Trust benefits from a wide diversification of asset types, investment fund strategies and external investment fund managers, and therefore has no significant concentration of risk.
The investment policy of the Master Trust outlines investment objectives and defines the responsibilities of the EBPB, external investment managers, investment advisor and trustee and custodian. The investment policy is reviewed annually by PPL's Board of Directors.
The EBPB created a risk management framework around the trust assets and pension liabilities. This framework considers the trust assets as being composed of three sub-portfolios: growth, immunizing and liquidity portfolios. The growth portfolio is comprised of investments that generate a return at a reasonable risk, including equity securities, certain debt securities and alternative investments. The immunizing portfolio consists of debt securities, generally with long durations, and derivative positions. The immunizing portfolio is designed to offset a portion of the change in the pension liabilities due to changes in interest rates. The liquidity portfolio consists primarily of cash and cash equivalents.
Target allocation ranges have been developed for each portfolio on a plan basis based on input from external consultants with a goal of limiting funded status volatility. The EBPB monitors the investments in each portfolio on a plan basis, and seeks to obtain a target portfolio that emphasizes reduction of risk of loss from market volatility. In pursuing that goal, the EBPB establishes revised guidelines from time to time. EBPB investment guidelines on a plan basis, as well as the weighted average of such guidelines, as of the end of 2013 are presented below.
The asset allocation for the trusts and the target allocation by portfolio, at December 31, are as follows:
									2013 Target Asset Allocation (a)
			Percentage of trust assets							Weighted
				2013 (a)			2012			Average			PPL Plans			LKE Plans
Growth Portfolio				59%			58%			55%			55%			55%
	Equity securities			30%			31%
	Debt securities (b)			17%			18%
	Alternative investments			12%			9%
Immunizing Portfolio				39%			41%			43%			43%			43%
	Debt securities (b)			40%			40%
	Derivatives			-1%			1%
Liquidity Portfolio				2%			1%			2%			2%			2%
Total				100%			100%			100%			100%			100%
(a)       Allocations exclude consideration of cash for the WKE Bargaining Employees' Retirement Plan and a guaranteed 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.
(PPL Energy Supply)
PPL Montana, a subsidiary of PPL Energy Supply, has a pension plan whose assets are invested solely in the PPL Services Corporation Master Trust, which is fully disclosed below. The fair value of this plan's assets of $147 million and $149 million at December 31, 2013 and 2012 represents an interest of approximately 3% and 4% in the Master Trust.
(LKE)
LKE has pension plans, including LG&E's plan, whose assets are invested solely in the PPL Services Corporation Master Trust, which is fully disclosed below. The fair value of these plans' assets of $1.2 billion and $1.1 billion at December 31, 2013 and 2012 represents an interest of approximately 29% and 26% in the Master Trust.
(LG&E)
LG&E has a pension plan whose assets are invested solely in the PPL Services Corporation Master Trust, which is fully disclosed below. The fair value of this plan's assets of $281 million and $287 million at December 31, 2013 and 2012 represents an interest of approximately 7% in the Master Trust for both years.
(All Registrants except PPL Electric and KU)
The fair value of net assets in the U.S. pension plan trusts by asset class and level within the fair value hierarchy was:
					December 31, 2013												December 31, 2012
								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					$	120		$	120								$	84		$	84
Equity securities:
		U.S.:
			Large-cap			480			134		$	346						558			206		$	352
			Small-cap			137			137									124			124
			Commingled debt			749			13			736						676			56			620
		International				630			163			467						557			184			373
Debt securities:
		U.S. Treasury and U.S. government sponsored
			agency			617			563			54						704			634			70
		Residential/commercial backed securities				12						11		$	1			12						11		$	1
		Corporate				963						940			23			874						847			27
		Other				24						24						24						23			1
		International				7						7						7						7
Alternative investments:
		Commodities				108						108						59						59
		Real estate				134						134						93						93
		Private equity				80									80			75									75
		Hedge funds				210						210						125						125
Derivatives:
		Interest rate swaps and swaptions				-49						-49						36						36
		Other				12						12						2						2
Insurance contracts						37									37			42									42
PPL Services Corporation Master Trust assets, at
	fair value					4,271		$	1,130		$	3,000		$	141			4,052		$	1,288		$	2,618		$	146
Receivables and payables, net (a)																		-11
401(h) account restricted for other
	postretirement benefit obligations					-115												-102
Total PPL Services Corporation Master Trust
	pension assets				$	4,156											$	3,939
(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2013 is as follows:
						Residential/
						commercial
						backed			Corporate			Private			Insurance			Other
						securities			debt			equity			contracts			debt			Total
Balance at beginning of period						$	1		$	27		$	75		$	42		$	1		$	146
	Actual return on plan assets
			Relating to assets still held
				at the reporting date									3			2						5
			Relating to assets sold during the period							5												5
	Purchases, sales and settlements									-9			2			-7						-14
	Transfers from level 3 to level 2																		-1			-1
Balance at end of period						$	1		$	23		$	80		$	37		$			$	141
A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2012 is as follows:
						Residential/
						commercial
						backed			Corporate			Private			Insurance			Other
						securities			debt			equity			contracts			debt			Total
Balance at beginning of period									$	7		$	45		$	46					$	98
	Actual return on plan assets
			Relating to assets still held
				at the reporting date						1			10			3						14
			Relating to assets sold during the period							2												2
	Purchases, sales and settlements					$	1			21			20			-7						35
	Transfers from level 2 to level 3																	$	1			1
	Transfers from level 3 to level 2									-4												-4
Balance at end of period						$	1		$	27		$	75		$	42		$	1		$	146
The fair value measurements of cash and cash equivalents are based on the amounts on deposit.
The market approach is used to measure fair value of equity securities. The fair value measurements of equity securities (excluding commingled funds), which are generally classified as Level 1, are based on quoted prices in active markets. These securities represent actively and passively managed investments that are managed against various equity indices.
Investments in commingled equity and debt funds are categorized as equity securities. These investments are classified as Level 2, except for exchange-traded funds, which are classified as Level 1 based on quoted prices in active markets. The fair value measurements for Level 2 investments are based on firm quotes of net asset values per share, which are not considered obtained from a quoted price in an active market. 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 evaluated prices that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. The fair value of debt securities is generally measured using a market approach, including the use of pricing models which incorporate observable inputs. Common inputs include benchmark yields, reported trades, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as monthly payment data, future predicted cash flows, collateral performance and new issue data. For the PPL Services Corporation Master Trust, these securities represent investments in securities issued by U.S. Treasury and U.S. government sponsored agencies; investments securitized by residential mortgages, auto loans, credit cards and other pooled loans; investments in investment grade and non-investment grade bonds issued by U.S. companies across several industries; investments in debt securities issued by foreign governments and corporations; and exchange traded funds.
Investments in commodities represent ownership of units of a commingled fund that is invested as a long-only, unleveraged portfolio of exchange-traded futures and forward contracts in tangible commodities to obtain broad exposure to all principal groups in the global commodity markets, including energies, agriculture and metals (both precious and industrial) using proprietary commodity trading strategies. The fund has daily liquidity with a specified notification period. The fund's fair value is based upon a unit value as calculated by the fund's trustee.
Investments in real estate represent an investment in a partnership whose purpose is to manage investments in core U.S. real estate properties diversified geographically and across major property types (e.g., office, industrial, retail, etc.). The manager is focused on properties with high occupancy rates with quality tenants. This results in a focus on high income and stable cash flows with appreciation being a secondary factor. Core real estate generally has a lower degree of leverage when compared with more speculative real estate investing strategies. The partnership has limitations on the amounts that may be redeemed based on available cash to fund redemptions. Additionally, the general partner may decline to accept redemptions when necessary to avoid adverse consequences for the partnership, including legal and tax implications, among others. The fair value of the investment is based upon a partnership unit value.
Investments in private equity represent interests in partnerships in multiple early-stage venture capital funds and private equity fund of funds that use a number of diverse investment strategies. Four of the partnerships have limited lives of ten years, while the fifth has a life of 15 years, after which liquidating distributions will be received. Prior to the end of each partnership's life, the investment cannot be redeemed with the partnership; however, the interest may be sold to other parties, subject to the general partner's approval. The PPL Services Corporation Master Trust has unfunded commitments of $76 million that may be required during the lives of the partnerships. Fair value is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed.
Investments in hedge funds represent investments in three hedge fund of funds. Hedge funds seek a return utilizing a number of diverse investment strategies. The strategies, when combined aim to reduce volatility and risk while attempting to deliver positive returns under all market conditions. Major investment strategies for the hedge fund of funds include long/short equity, market neutral, distressed debt, and relative value. Generally, shares may be redeemed with 65 to 95 days prior written notice. The funds are subject to short term lockups and have limitations on the amount that may be withdrawn based on a percentage of the total net asset value of the fund, among other restrictions. All withdrawals are subject to the general partner's approval. The fair value for two of the funds has been estimated using the net asset value per share and the third fund's fair value is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed.
The fair value measurements of derivative instruments utilize various inputs that include quoted prices for similar contracts or market-corroborated inputs. In certain instances, these instruments may be valued using models, including standard option valuation models and standard industry models. These securities primarily represent investments in interest rate swaps and swaptions (the option to enter into an interest rate swap) which are valued based on the swap details, such as swap curves, notional amount, index and term of index, reset frequency, volatility and payer/receiver credit ratings.
Insurance contracts, classified as Level 3, represent an investment in an immediate participation guaranteed group annuity contract. The fair value is based on contract value, which represents cost plus interest income less distributions for benefit payments and administrative expenses.
Plan Assets - U.S. Other Postretirement Benefit Plans
The investment strategy with respect to other postretirement benefit obligations is to fund VEBA trusts and/or 401(h) accounts with voluntary contributions and to invest in a tax efficient manner. Excluding the 401(h) accounts included in the PPL Services Corporation Master Trust, other postretirement benefit plans are invested in a mix of assets for long-term growth with an objective of earning returns that provide liquidity as required for benefit payments. These plans benefit from diversification of asset types, investment fund strategies and investment fund managers, and therefore, have no significant concentration of risk. Equity securities include investments in domestic large-cap commingled funds. Ownership interests in commingled funds that invest entirely in debt securities are classified as equity securities, but treated as debt securities for asset allocation and target allocation purposes. Ownership interests in money market funds are treated as cash and cash equivalents for asset allocation and target allocation purposes. The asset allocation for the PPL VEBA trusts, excluding LKE, and the target allocation, by asset class, at December 31 are detailed below.
									Target Asset
			Percentage of plan assets						Allocation
			2013			2012			2013
Asset Class
U.S. Equity securities				55%			46%			45%
Debt securities (a)				41%			51%			50%
Cash and cash equivalents (b)				4%			3%			5%
	Total			100%			100%			100%
(a)       Includes commingled debt funds and debt securities.
(b)       Includes money market funds.
LKE's other postretirement benefit plan is invested primarily in a 401(h) account, with insignificant amounts invested in money market funds within VEBA trusts for liquidity.
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, 2013												December 31, 2012
								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					$	12		$	12								$	13		$	13
U.S. Equity securities:
		Large-cap				182					$	182						145					$	145
		Commingled debt				100						100						119						119
Debt securities:
		Municipalities				36						36						41						41
Total VEBA trust assets, at fair value						330		$	12		$	318						318		$	13		$	305
Receivables and payables, net (a)						1												1
401(h) account assets (b)						115												102
Total other postretirement benefit plan
	assets				$	446											$	421
(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
(b)       LKE's other postretirement benefit plan was invested primarily in a 401(h) account as disclosed in the PPL Services Corporation Master Trust.
Investments in money market funds represent investments in funds that invest primarily in a diversified portfolio of investment grade money market instruments, including, but not limited to, commercial paper, notes, repurchase agreements and other evidences of indebtedness with a maturity not exceeding 13 months from the date of purchase. The primary objective of the fund is a high level of current income consistent with stability of principal and liquidity. Redemptions can be made daily on this fund.
Investments in large-cap equity securities represent investments in a passively managed equity index fund that invests in securities and a combination of other collective funds. Fair value measurements are not obtained from a quoted price in an active market but are based on firm quotes of net asset values per share as provided by the trustee of the fund. Redemptions can be made daily on this fund.
Investments in commingled debt securities represent investments in a fund that invests in a diversified portfolio of investment grade long-duration fixed income securities. Redemptions can be made weekly on these funds.
Investments in municipalities represent investments in a diverse mix of tax-exempt municipal securities. The fair value measurements for these securities are based on recently executed transactions for identical securities or for similar securities.
Plan Assets - U.K. Pension Plans (PPL)
The overall investment strategy of WPD's pension plans is developed by each plan's independent trustees in its Statement of Investment Principles in compliance with the U.K. Pensions Act of 1995 and other U.K. legislation. The trustees' primary focus is to ensure that assets are sufficient to meet members' benefits as they fall due with a longer term objective to reduce investment risk. The investment strategy is intended to maximize investment returns while not incurring excessive volatility in the funding position. WPD's plans are invested in a wide diversification of asset types, fund strategies and fund managers; and therefore, have no significant concentration of risk. Commingled funds that consist entirely of debt securities are traded as equity units, but treated by WPD as debt securities for asset allocation and target allocation purposes. These include investments in U.K. corporate bonds and U.K. gilts.
The asset allocation and target allocation at December 31 of WPD's pension plans are detailed below.
									Target Asset
			Percentage of plan assets						Allocation
			2013			2012			2013
Asset Class
Equity securities
	U.K.			7%			6%			7%
	European (excluding the U.K.)			5%			14%			4%
	Asian-Pacific			3%						3%
	North American			5%						5%
	Emerging markets			8%			3%			8%
	Currency			7%			2%			3%
	Global Tactical Asset Allocation			19%			18%			19%
Debt securities (a)				40%			51%			45%
Alternative investments				6%			6%			6%
	Total			100%			100%			100%
(a)       Includes commingled debt funds.
The fair value of assets in the U.K. pension plans by asset class and level within the fair value hierarchy was:
					December 31, 2013												December 31, 2012
								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					$	10		$	10								$	14		$	14
Equity securities:
		U.K. companies				523			267		$	256						440			223		$	217
		European companies (excluding the U.K.)				355			275			80						956			720			236
		Asian-Pacific companies				226			180			46
		North American companies				352			254			98
		Emerging markets companies				411			126			285						231						231
		Global Equities				161						161
		Currency				485						485						127						127
		Global Tactical Asset Allocation				1,384						1,384						1,220						1,220
		Commingled debt:
			U.K. corporate bonds			504						504						593						593
			U.K. gilts			2,426						2,426						2,907						2,907
Alternative investments:
		Real estate				447						447						423						423
Fair value - U.K. pension plans					$	7,284		$	1,112		$	6,172					$	6,911		$	957		$	5,954
Except for investments in real estate, the fair value measurements of WPD's pension plan assets are based on the same inputs and measurement techniques used to measure the U.S. pension plan assets described above.
Investments in equity securities represent actively and passively managed funds that are measured against various equity indices. The Global Tactical Asset Allocation strategy attempts to benefit from short-term market inefficiencies by taking positions in worldwide markets with the objective to profit from relative movements across those markets.
U.K. corporate bonds include investment grade corporate bonds of companies from diversified U.K. industries.
U.K. gilts include gilts, index-linked gilts and swaps intended to track a portion of the plans' liabilities.
Investments in real estate represent holdings in a U.K. unitized fund that owns and manages U.K. industrial and commercial real estate with a strategy of earning current rental income and achieving capital growth. The fair value measurement of the fund is based upon a net asset value per share, which is based on the value of underlying properties that are independently appraised in accordance with Royal Institution of Chartered Surveyors valuation standards at least annually with quarterly valuation updates based on recent sales of similar properties, leasing levels, property operations and/or market conditions. The fund may be subject to redemption restrictions in the unlikely event of a large forced sale in order to ensure other unit holders are not disadvantaged.
Expected Cash Flows - U.S. Defined Benefit Plans (PPL)
PPL's U.S. defined benefit plans have the option to utilize available prior year credit balances to meet current and future contribution requirements. However, PPL contributed $96 million to its U.S. pension plans in January 2014.
PPL sponsors various non-qualified supplemental pension plans for which no assets are segregated from corporate assets. PPL expects to make approximately $8 million of benefit payments under these plans in 2014.
PPL is not required to make contributions to its other postretirement benefit plans but has historically funded these plans in amounts equal to the postretirement benefit costs recognized. Continuation of this past practice would cause PPL to contribute $21 million to its other postretirement benefit plans in 2014.
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
2014		$	211		$	53		$	1
2015			222			55			1
2016			234			57			1
2017			250			59			1
2018			264			62			1
2019-2023			1,545			338			3
(PPL Energy Supply)
The PPL Montana pension plan has the option to utilize available prior year credit balances to meet current and future contribution requirements. However, PPL Montana contributed $6 million to its pension plan in January 2014.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans.
					Other
		Pension			Postretirement
2014		$	5		$	1
2015			6			2
2016			6			2
2017			7			2
2018			8			2
2019-2023			52			11
(LKE)
LKE's defined benefit plans have the option to utilize available prior year credit balances to meet current and future contribution requirements. However, LKE contributed $35 million to its pension plans in January 2014.
LKE sponsors various non-qualified supplemental pension plans for which no assets are segregated from corporate assets. LKE expects to make $3 million of benefit payments under these plans in 2014.
LKE is not required to make contributions to its other postretirement benefit plan but has historically funded this plan in amounts equal to the postretirement benefit costs recognized. Continuation of this past practice would cause LKE to contribute $13 million to its other postretirement benefit plan in 2014.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by LKE.
					Other Postretirement
								Expected
					Benefit			Federal
			Pension		Payment			Subsidy
2014		$	58		$	13		$	1
2015			57			13
2016			60			14			1
2017			64			14
2018			69			15			1
2019-2023			425			81			2
(LG&E)
LG&E's defined benefit plan has the option to utilize available prior year credit balances to meet current and future contribution requirements. LG&E does not plan to contribute to its pension plan in 2014.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plan.
			Pension
2014		$	15
2015			15
2016			15
2017			16
2018			17
2019-2023			99
Expected Cash Flows - U.K. Pension Plans (PPL)
The pension plans of WPD are subject to formal actuarial valuations every three years, which are used to determine funding requirements. Contribution requirements for periods after April 1, 2014 were evaluated in accordance with the draft valuations performed as of March 31, 2013. Contributions for periods prior to March 31, 2014 were based on a valuation as of June 30, 2011 for the PPL WEM plan and as of March 31, 2010 for the PPL WW plan. WPD expects to make contributions of approximately $313 million in 2014. WPD is currently permitted to recover in rates approximately 75% of their deficit funding requirements for their primary pension plans.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans.
		Pension
2014		$	387
2015			392
2016			397
2017			402
2018			410
2019-2023			2,128
Savings Plans (All Registrants)
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:
		2013			2012			2011
PPL		$	41		$	36		$	31
PPL Energy Supply			12			12			11
PPL Electric			6			5			5
LKE			13			12			11
LG&E			7			6			5
KU			6			6			6
(PPL, PPL Energy Supply and PPL Electric)
Employee Stock Ownership Plan
PPL sponsors a non-leveraged ESOP in which domestic employees, excluding those of PPL Montana, LKE and the mechanical contractors, are enrolled on the first day of the month following eligible employee status. Dividends paid on ESOP shares are treated as ordinary dividends by PPL. Under existing income tax laws, PPL is permitted to deduct the amount of those dividends for income tax purposes and to contribute the resulting tax savings (dividend-based contribution) to the ESOP.
The dividend-based contribution, which is discretionary, is used to buy shares of PPL's common stock and is expressly conditioned upon the deductibility of the contribution for federal income tax purposes. Contributions to the ESOP are allocated to eligible participants' accounts as of the end of each year, based 75% on shares held in existing participants' accounts and 25% on the eligible participants' compensation.
For 2013, PPL did not record compensation expense related to the ESOP as no contribution will be made. Compensation expense for ESOP contributions was $8 million in 2012 and 2011. These amounts were offset by the dividend-based contribution tax savings and had no impact on PPL's earnings.
PPL shares within the ESOP at December 31, 2013 were 7,699,472, or 1% of total common shares outstanding, and are included in all EPS calculations.
Separation Benefits
Certain PPL subsidiaries provide separation benefits to eligible employees. These benefits may be provided in the case of separations due to performance issues, loss of job related qualifications or organizational changes. Until December 1, 2012, certain employees separated were eligible for cash severance payments, outplacement services, accelerated stock award vesting, continuation of group health and welfare coverage, and enhanced pension and postretirement medical benefits. As of December 1, 2012, separation benefits for certain employees were changed to eliminate accelerated stock award vesting and enhanced pension and postretirement medical benefits. Also, the continuation of group health and welfare coverage was replaced with a single sum payment approximating the dollar amount of premium payments that would be incurred for continuation of group health and welfare coverage. Separation benefits are recorded when such amounts are probable and estimable.
Separation benefits were not significant in 2013 and 2012.
See Note 10 for separation benefits recorded in 2011 in connection with a reorganization following the acquisition of WPD Midlands.

Jointly_Owned_Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2013
Jointly Owned Facilities [Line Items]	'
Jointly Owned Facilities	'
	14. Jointly Owned Facilities
	(All Registrants except PPL Electric)
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
KU
	31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
In addition to the interests mentioned above, at December 31, 2012, PPL Montana had a 50% leasehold interest in Colstrip Units 1 and 2 and a 30% leasehold interest in Colstrip Unit 3 under operating leases. In December 2013, PPL Montana terminated the operating lease arrangement and acquired these interests. See Note 8 for additional information. At December 31, 2013, the book value of the acquired assets was not significant. At December 31, 2013 and 2012, NorthWestern owned a 30% interest in Colstrip Unit 4. PPL Montana and NorthWestern have a sharing agreement that governs each party's responsibilities and rights relating to the operation of Colstrip Units 3 and 4. Under the terms of that agreement, each party is responsible for 15% of the total non-coal operating and construction costs of Colstrip Units 3 and 4, regardless of whether a particular cost is specific to Colstrip Unit 3 or 4, and is entitled to take up to the same percentage of the available generation from Units 3 and 4.
PPL Energy Supply LLC [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Facilities	'
	14. Jointly Owned Facilities
	(All Registrants except PPL Electric)
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
KU
	31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
In addition to the interests mentioned above, at December 31, 2012, PPL Montana had a 50% leasehold interest in Colstrip Units 1 and 2 and a 30% leasehold interest in Colstrip Unit 3 under operating leases. In December 2013, PPL Montana terminated the operating lease arrangement and acquired these interests. See Note 8 for additional information. At December 31, 2013, the book value of the acquired assets was not significant. At December 31, 2013 and 2012, NorthWestern owned a 30% interest in Colstrip Unit 4. PPL Montana and NorthWestern have a sharing agreement that governs each party's responsibilities and rights relating to the operation of Colstrip Units 3 and 4. Under the terms of that agreement, each party is responsible for 15% of the total non-coal operating and construction costs of Colstrip Units 3 and 4, regardless of whether a particular cost is specific to Colstrip Unit 3 or 4, and is entitled to take up to the same percentage of the available generation from Units 3 and 4.
LG And E And KU Energy LLC [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Facilities	'
	14. Jointly Owned Facilities
	(All Registrants except PPL Electric)
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
KU
	31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
In addition to the interests mentioned above, at December 31, 2012, PPL Montana had a 50% leasehold interest in Colstrip Units 1 and 2 and a 30% leasehold interest in Colstrip Unit 3 under operating leases. In December 2013, PPL Montana terminated the operating lease arrangement and acquired these interests. See Note 8 for additional information. At December 31, 2013, the book value of the acquired assets was not significant. At December 31, 2013 and 2012, NorthWestern owned a 30% interest in Colstrip Unit 4. PPL Montana and NorthWestern have a sharing agreement that governs each party's responsibilities and rights relating to the operation of Colstrip Units 3 and 4. Under the terms of that agreement, each party is responsible for 15% of the total non-coal operating and construction costs of Colstrip Units 3 and 4, regardless of whether a particular cost is specific to Colstrip Unit 3 or 4, and is entitled to take up to the same percentage of the available generation from Units 3 and 4.
Louisville Gas And Electric Co [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Facilities	'
	14. Jointly Owned Facilities
	(All Registrants except PPL Electric)
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
KU
	31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
In addition to the interests mentioned above, at December 31, 2012, PPL Montana had a 50% leasehold interest in Colstrip Units 1 and 2 and a 30% leasehold interest in Colstrip Unit 3 under operating leases. In December 2013, PPL Montana terminated the operating lease arrangement and acquired these interests. See Note 8 for additional information. At December 31, 2013, the book value of the acquired assets was not significant. At December 31, 2013 and 2012, NorthWestern owned a 30% interest in Colstrip Unit 4. PPL Montana and NorthWestern have a sharing agreement that governs each party's responsibilities and rights relating to the operation of Colstrip Units 3 and 4. Under the terms of that agreement, each party is responsible for 15% of the total non-coal operating and construction costs of Colstrip Units 3 and 4, regardless of whether a particular cost is specific to Colstrip Unit 3 or 4, and is entitled to take up to the same percentage of the available generation from Units 3 and 4.
Kentucky Utilities Co [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Facilities	'
	14. Jointly Owned Facilities
	(All Registrants except PPL Electric)
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
KU
	31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
In addition to the interests mentioned above, at December 31, 2012, PPL Montana had a 50% leasehold interest in Colstrip Units 1 and 2 and a 30% leasehold interest in Colstrip Unit 3 under operating leases. In December 2013, PPL Montana terminated the operating lease arrangement and acquired these interests. See Note 8 for additional information. At December 31, 2013, the book value of the acquired assets was not significant. At December 31, 2013 and 2012, NorthWestern owned a 30% interest in Colstrip Unit 4. PPL Montana and NorthWestern have a sharing agreement that governs each party's responsibilities and rights relating to the operation of Colstrip Units 3 and 4. Under the terms of that agreement, each party is responsible for 15% of the total non-coal operating and construction costs of Colstrip Units 3 and 4, regardless of whether a particular cost is specific to Colstrip Unit 3 or 4, and is entitled to take up to the same percentage of the available generation from Units 3 and 4.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies [Abstract]	'
Commitments and Contingencies	'
	15. Commitments and Contingencies
	Energy Purchases, Energy Sales and Other Commitments
	Energy Purchase Commitments
	(PPL and PPL Energy Supply)
	PPL Energy Supply enters into long-term energy and energy related contracts which include commitments to purchase:
		Maximum
		Maturity
	Contract Type	Date
	Fuels (a)	2023
	Limestone	2030
	Natural Gas Storage	2015
	Natural Gas Transportation	2032
	Power, excluding wind	2021
	RECs	2021
	Wind Power	2027
	(a)       PPL Energy Supply incurred pre-tax charges of $29 million during 2012 to reduce its 2012 and 2013 contracted coal deliveries. These charges were recorded to "Fuel" on the Statement of Income.
	(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	2019
	Coal Transportation and Fleeting Services	2024
	Natural Gas Storage	2024
	Natural Gas Transportation	2024
	LG&E and KU have a power purchase agreement with OVEC expiring in June 2040. See footnote (i) 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 as follows:
		LG&E			KU			Total
	2014	$	18		$	8		$	26
	2015		18			8			26
	2016		18			8			26
	2017		19			8			27
	2018		20			9			29
	Thereafter		504			224			728
		$	597		$	265		$	862
	In addition, LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows:
		2013			2012			2011
	LG&E	$	18		$	20		$	22
	KU		8			9			10
	Total	$	26		$	29		$	32
	(PPL and PPL Electric)
	In May 2012, PPL Electric filed a plan with the PUC to purchase its electricity supply for default customers for the period June 2013 through May 2015. The PUC approved the plan in January 2013. The approved plan provides that PPL Electric procure this electricity through competitive solicitations twice each plan year beginning in April 2013. The solicitations will include layered short-term full-requirement products ranging from three months to 12 months for residential and small commercial and industrial PLR customers as well as a recurring 12 month spot market product for large commercial and industrial PLR customers. To date, two of four solicitations have been completed.
	(PPL Electric)
	See Note 16 for information on the power supply agreements between PPL EnergyPlus and PPL Electric.
	Energy Sales Commitments
	(PPL and PPL Energy Supply)
	In connection with its marketing activities or hedging strategy for its power plants, PPL Energy Supply has entered into long-term power sales contracts that extend into 2020, excluding long-term renewable energy agreements that extend into 2038.
	(PPL Energy Supply)
	See Note 16 for information on the power supply agreements between PPL EnergyPlus and PPL Electric.
	PPL Montana Hydroelectric License Commitments (PPL and PPL Energy Supply)
	PPL Montana owns and operates 11 hydroelectric facilities and one storage reservoir licensed by the FERC under long-term licenses pursuant to the Federal Power Act. Pursuant to Section 8(e) of the Federal Power Act, the FERC approved the transfer from Montana Power to PPL Montana of all pertinent licenses in connection with the Montana Asset Purchase Agreement.
	The Kerr Dam Project license (50-year term) was issued by the FERC jointly to Montana Power and the Confederated Salish and Kootenai Tribes of the Flathead Nation in 1985, and requires PPL Montana (as successor licensee to Montana Power) to hold and operate the project for at least 30 years (to 2015). Between 2015 and 2025, the tribes have the option to purchase, hold and operate the project for the remainder of the license term, which expires in 2035. Although the tribes have indicated their intent to exercise the option at the earliest possible date, PPL Montana cannot predict if and when this option will be exercised.
	PPL Montana entered into two Memoranda of Understanding (MOUs) with state, federal and private entities related to the issuance in 2000 of the FERC renewal license for the nine dams comprising the Missouri-Madison project. The MOUs are periodically updated and renewed and require PPL Montana to implement plans to mitigate the impact of its projects on fish, wildlife and their habitats, and to increase recreational opportunities. The MOUs were created to maximize collaboration between the parties and enhance the possibility to receive matching funds from relevant federal agencies. Under these arrangements, PPL Montana has a remaining commitment to spend $29 million between 2014 and 2040.
	In September 2013, PPL Montana reached an agreement to sell its hydroelectric facilities to NorthWestern. The agreement includes PPL Montana's 11 hydroelectric power plants and the company's Hebgen Lake reservoir. See Note 8 for additional information.
	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 (h) to the table in "Guarantees and Other Assurances" below for information on an LKE indemnity relating to its former WKE lease, including related legal proceedings.
	(PPL and PPL Energy Supply)
	Montana Hydroelectric Litigation
	As previously reported, in February 2012 the U.S. Supreme Court issued a decision overturning decisions by the Montana First Judicial District Court and the Montana Supreme Court which had held that the streambeds underlying PPL Montana's hydroelectric generating facilities were owned by the State of Montana and that PPL Montana owed the State of Montana compensation for its prior use of those streambeds. As a result of the U.S. Supreme Court decision, PPL Montana reversed its total loss accrual resulting in a $65 million net credit to "Other operation and maintenance" and a $10 million net credit to "Interest Expense" on the Statement of Income in 2011. The case was remanded by the U.S. Supreme Court to the Montana Supreme Court and, in April 2012, returned by the Montana Supreme Court to the Montana First Judicial District Court.  Further proceedings have not been scheduled by the district court.
	Bankruptcy of SMGT
	In October 2011, SMGT, a Montana cooperative and purchaser of electricity under a long-term supply contract with PPL EnergyPlus expiring in June 2019 (SMGT Contract), filed for protection under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the District of Montana (Bankruptcy Court). At the time of the bankruptcy filing, SMGT was PPL EnergyPlus' largest unsecured credit exposure. This contract was accounted for as NPNS by PPL EnergyPlus.
The SMGT Contract provided for fixed volume purchases on a monthly basis at established prices. Pursuant to a court order and subsequent stipulations entered into between the SMGT bankruptcy trustee and PPL EnergyPlus, since the date of its Chapter 11 filing through January 2012, SMGT continued to purchase electricity from PPL EnergyPlus at the price specified in the SMGT Contract and made timely payments for such purchases, but at lower volumes than as prescribed in the SMGT Contract. In January 2012, the trustee notified PPL EnergyPlus that SMGT would not purchase electricity under the SMGT Contract for the month of February. In March 2012, the Bankruptcy Court issued an order approving the request of the SMGT trustee and PPL EnergyPlus to terminate the SMGT Contract, effective April 1, 2012. As a result, PPL EnergyPlus was free to resell to other customers the electricity previously contracted to SMGT.
PPL EnergyPlus' receivable under the SMGT Contract, representing non-performance by SMGT prior to termination of the SMGT Contract, totaled approximately $21 million at December 31, 2012, which has been fully reserved.
In July 2012, PPL EnergyPlus filed its proof of claim in the SMGT bankruptcy proceeding. The total claim, including the above receivable, is approximately $375 million, predominantly an unsecured claim representing the value for energy sales that will not occur as a result of the termination of the SMGT Contract. No assurance can be given as to the collectability of the claim and, therefore, no amounts have been recorded in the 2013 financial statements.
Sierra Club Litigation
In July 2012, PPL Montana received a Notice of Intent to Sue (Notice) for violations of the Clean Air Act at Colstrip Steam Electric Station (Colstrip) from counsel on behalf of the Sierra Club and the Montana Environmental Information Center (MEIC). An Amended Notice was received on September 4, 2012, and a Second Amended Notice was received in October 2012. A Supplemental Notice was received in December 2012.  The Notice, Amended Notice, Second Amended Notice and Supplemental Notice (the Notices) were all addressed to the Owner or Managing Agent of Colstrip, and to the other Colstrip co-owners: Avista Corporation, Puget Sound Energy, Portland General Electric Company, Northwestern Energy and PacificCorp.  The Notices allege certain violations of the Clean Air Act, including New Source Review, Title V and opacity requirements.
On March 6, 2013, the Sierra Club and MEIC filed a complaint against PPL Montana and the other Colstrip co-owners in the U.S. District Court, District of Montana, Billings Division. PPL Montana operates Colstrip on behalf of the co-owners. The complaint is generally consistent with the prior Notices and lists 39 separate claims for relief. All but three of the claims allege Prevention of Significant Deterioration (PSD) related violations under the federal Clean Air Act for various plant maintenance projects completed since 1992. For each such project or set of projects, there are separate claims for failure to obtain a PSD permit, for failure to obtain a Montana Air Quality Permit to operate after the project(s) were completed and for operating after completion of such project(s) without "Best Available Control Technology". The remaining three claims relate to the alleged failure to update the Title V operating permit for Colstrip to reflect the alleged major modifications described in the other claims, allege that the previous Title V compliance certifications were incomplete because they did not address the major plant modifications, and that numerous opacity violations have occurred at the plant since 2007. The complaint requests injunctive relief and civil penalties on average of $36,000 per day per violation, including a request that the owners remediate environmental damage and that $100,000 of the civil penalties be used for beneficial mitigation projects. In January 2014, trial in this matter as to liability was re-scheduled for March 2015. A new date for trial as to remedies, if there is a finding of liability, has not been scheduled.
On July 27, 2013, the Sierra Club and MEIC filed an additional Notice, identifying additional plant projects that are alleged not to be in compliance with the Clean Air Act. On September 27, 2013, the plaintiffs filed an amended complaint. This amended complaint drops all claims regarding pre-2001 plant projects, as well as the plaintiffs' Title V and opacity claims. It does, however, add claims with respect to a number of post-2000 plant projects, which effectively increased the number of projects subject to the litigation by about 40. PPL Montana and the other Colstrip Owners filed a motion to dismiss the amended complaint on October 11, 2013. Although PPL Montana believes it and the other co-owners have numerous defenses to the allegations set forth in this complaint and will vigorously assert the same, PPL Montana cannot predict the ultimate outcome of this matter at this time.
Regulatory Issues
(All Registrants except PPL Energy Supply)
See Note 6 for information on regulatory matters related to utility rate regulation.
Enactment of Financial Reform Legislation (All Registrants)
The Dodd-Frank Act became effective in July 2010 and includes provisions that impose derivative transaction reporting requirements and require most over-the-counter derivative transactions to be executed through an exchange and to be centrally cleared. The Dodd-Frank Act also provides that the U.S. Commodity Futures Trading Commission (CFTC) may impose collateral and margin requirements for over-the-counter derivative transactions, as well as capital requirements for certain entity classifications. The CFTC is establishing final rules on major provisions in the Dodd-Frank Act through its rulemaking process. Several final rules providing for the definition of the terms "swap", "swap dealer", and "major swap participant" became effective in October 2012. The entity classification thresholds and requirements set forth in these final rules do not require the Registrants to register as either swap dealers or major swap participants. Consequently, as commercial end users, the Registrants are not subject to the heightened regulatory requirements applicable to swap dealers or major swap participants, including Business Conduct Standards, enhanced recordkeeping and reporting, clearing and exchange trading of CFTC-mandated swaps and other complex requirements under other CFTC regulations. The Dodd-Frank Act and its implementing regulations, however, have imposed on the Registrants significant additional and costly recordkeeping, reporting and documentation requirements.
The Registrants could face significantly higher operating costs or may be required to post additional collateral if they or their counterparties are subject to capital or margin requirements as ultimately adopted in the implementing regulations of the Dodd-Frank Act. Additionally, the burden that the Dodd-Frank Act and implementing regulations impose on all market participants could cause decreased liquidity in the bilateral swap market as financial entities discontinue their proprietary trading operations. Decreased liquidity could increase costs for Registrants to successfully meet hedge targets. The Registrants will continue to evaluate the provisions of the Dodd-Frank Act and its implementing regulations, but could incur significant costs related to compliance with the Act and regulations.
(PPL, PPL Energy Supply and PPL Electric)
New Jersey Capacity Legislation
In January 2011, New Jersey enacted a law that intervenes in the wholesale capacity market exclusively regulated by the FERC: S. No. 2381, 214th Leg. (N.J. 2011) (the Act). To create incentives for the development of new, in-state electric generation facilities, the Act implements a "long-term capacity agreement pilot program (LCAPP)." The Act requires New Jersey utilities to pay a guaranteed fixed price for wholesale capacity, imposed by the New Jersey Board of Public Utilities (BPU), to certain new generators participating in PJM, with the ultimate costs of that guarantee to be borne by New Jersey ratepayers. PPL believes the intent and effect of the LCAPP is to encourage the construction of new generation in New Jersey even when, under the FERC-approved PJM economic model, such new generation would not be economic. The Act could depress capacity prices in PJM in the short term, impacting PPL Energy Supply's revenues, and harm the long-term ability of the PJM capacity market to incent necessary generation investment throughout PJM. In February 2011, the PJM Power Providers Group (P3), an organization in which PPL is a member, filed a complaint before the FERC seeking changes in PJM's capacity market rules designed to ensure that subsidized generation, such as the generation that may result from the implementation of the LCAPP, will not be able to set capacity prices artificially low as a result of their exercise of buyer market power. In April 2011, the FERC issued an order granting in part and denying in part P3's complaint and ordering changes in PJM's capacity rules consistent with a significant portion of P3's requested changes. Several parties have filed appeals of the FERC's order. PPL, PPL Energy Supply and PPL Electric cannot predict the outcome of this proceeding or the economic impact on their businesses or operations, or the markets in which they transact business.
In addition, in February 2011, PPL, and several other generating companies and utilities filed a complaint in U.S. District Court in New Jersey challenging the Act on the grounds that it violates well-established principles under the Supremacy Clause and the Commerce Clause of the U.S. Constitution and requesting declaratory and injunctive relief barring implementation of the Act by the BPU Commissioners. In October 2011, the court denied the BPU's motion to dismiss the proceeding and in September 2012 the U.S. District Court denied all summary judgment motions. Trial of this matter was completed in June 2013. In October 2013, the U.S. District Court in New Jersey issued a decision finding the Act unconstitutional under the Supremacy Clause on the grounds that it infringes upon the FERC's exclusive authority to regulate the wholesale sale of electricity in interstate commerce. The decision has been appealed to the U.S. Court of Appeals for the Third Circuit by CPV Power Development, Inc., Hess Newark, LLC and the State of New Jersey. Oral arguments are scheduled for March 27, 2014. PPL, PPL Energy Supply and PPL Electric cannot predict the outcome of this proceeding or the economic impact on their businesses or operations, or the markets in which they transact business.
Maryland Capacity Order
In April 2012, the Maryland Public Service Commission (MD PSC) ordered three electric utilities in Maryland to enter into long-term contracts to support the construction of new electric generating facilities in Maryland, specifically a 661 MW natural gas-fired combined-cycle generating facility to be owned by CPV Maryland, LLC. PPL believes the intent and effect of the action by the MD PSC is to encourage the construction of new generation in Maryland even when, under the FERC-approved PJM economic model, such new generation would not be economic. The MD PSC action could depress capacity prices in PJM in the short term, impacting PPL Energy Supply's revenues, and harm the long-term ability of the PJM capacity market to encourage necessary generation investment throughout PJM.
In April 2012, PPL and several other generating companies filed a complaint in U.S. District Court in Maryland challenging the MD PSC order on the grounds that it violates well-established principles under the Supremacy and Commerce clauses of the U.S. Constitution and requested declaratory and injunctive relief barring implementation of the order by the MD PSC Commissioners. In August 2012, the court denied the MD PSC and CPV Maryland, LLC motions to dismiss the proceeding. Trial of this matter was completed in March 2013. In September 2013, the U.S. District Court in Maryland issued a decision finding the MD PSC order unconstitutional under the Supremacy Clause on the grounds that it infringes upon the FERC's exclusive authority to regulate the wholesale sale of electricity in interstate commerce. The decision has been appealed to the U.S. Court of Appeals for the Fourth Circuit by CPV Power Development, Inc. and the State of Maryland. PPL, PPL Energy Supply, and PPL Electric cannot predict the outcome of this proceeding or the economic impact on their businesses or operations, or the markets in which they transact business.
Pacific Northwest Markets (PPL and PPL Energy Supply)
Through its subsidiaries, PPL Energy Supply made spot market bilateral sales of power in the Pacific Northwest during the period from December 2000 through June 2001. Several parties subsequently claimed refunds at FERC as a result of these sales. In June 2003, the FERC terminated proceedings to consider whether to order refunds for spot market bilateral sales made in the Pacific Northwest, including sales made by PPL Montana, during the period December 2000 through June 2001. In August 2007, the U.S. Court of Appeals for the Ninth Circuit reversed the FERC's decision and ordered the FERC to consider additional evidence. In October 2011, FERC initiated proceedings to consider additional evidence. In July 2012, PPL Montana and the City of Tacoma, one of the two parties claiming refunds at FERC, reached a settlement whereby PPL Montana paid $75 thousand to resolve the City of Tacoma's $23 million claim. The settlement does not resolve the remaining claim outstanding at December 31, 2013 by the City of Seattle for approximately $50 million. In April 2013, the FERC issued an order on reconsideration allowing the parties to seek refunds for the period January 2000 through December 2000. As a result, the City of Seattle may be able to seek refunds from PPL Montana for such period. Hearings before a FERC Administrative Law Judge regarding the City of Seattle's refund claims were completed in October 2013. Briefing was completed in January 2014 and an initial decision is expected in mid-March 2014.
Although PPL and its subsidiaries believe they have not engaged in any improper trading or marketing practices affecting the Pacific Northwest markets, PPL and PPL Energy Supply cannot predict the outcome of the above-described proceedings or whether any subsidiaries will be the subject of any additional governmental investigations or named in other lawsuits or refund proceedings. Consequently, PPL and PPL Energy Supply cannot estimate a range of reasonably possible losses, if any, related to this matter.
(All Registrants)
FERC Market-Based Rate Authority
In 1998, the FERC authorized LG&E, KU and PPL EnergyPlus to make wholesale sales of electricity and related products at market-based rates. In those orders, the FERC directed LG&E, KU and PPL EnergyPlus, respectively, to file an updated market analysis within three years after the order, and every three years thereafter. Since then, periodic market-based rate filings with the FERC have been made by LG&E, KU, PPL EnergyPlus, PPL Electric, PPL Montana and most of PPL Generation's subsidiaries. These filings consisted of a Northwest market-based rate filing for PPL Montana and a Northeast market-based rate filing for most of the other PPL subsidiaries in PJM's region. In June 2011, FERC approved PPL's market-based rate update for the Eastern and Western regions and PPL filed its market-based rate update for the Southeast region, including LG&E and KU in addition to PPL EnergyPlus. Also, in June 2011, the FERC issued an order approving LG&E's and KU's request for a determination that they no longer be deemed to have market power in the BREC balancing area and removing restrictions on their market-based rate authority in such region. In December 2013, PPL filed market-based rate updates for the Eastern and Western regions. PPL cannot predict the ultimate outcome of these update filings at this time.
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.
LG&E, KU, PPL Electric and certain subsidiaries of PPL Energy Supply monitor their compliance with the Reliability Standards and continue to self-report potential violations of certain applicable reliability requirements and submit accompanying mitigation plans, as required. The resolution of a 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, other than the amounts currently recorded.
In October 2012, the FERC initiated its consideration of proposed changes to Reliability Standards to address the impacts of Geomagnetic Disturbances on the reliable operation of the bulk-power system, which might, among other things, lead to a requirement to install equipment that blocks geo-magnetically induced currents on implicated transformers. On May 16, 2013, FERC issued Order No. 779, requiring NERC to submit two types of Reliability Standards for FERC's approval in twelve month intervals. The first type would require certain owners and operators of the nation's electricity infrastructure, such as the Registrants, to develop and implement operational procedures to mitigate the effects of Geomagnetic Disturbances on the bulk-power system. This NERC proposed standard was filed by NERC with FERC for approval in January of 2014, with a comment due date of March 24, 2014. The second type is to require owners and operators of the bulk-power system to assess certain Geomagnetic Disturbance events and develop and implement plans to protect the bulk-power system from those events and must be filed by NERC with FERC for approval by January 22, 2015. The Registrants may be required to make significant expenditures in new equipment or modifications to their facilities to comply with the new requirements. The Registrants are unable to predict the amount of any expenditures that may be required as a result of the adoption of any Reliability Standards for Geomagnetic Disturbances.
Settled Litigation (PPL and PPL Energy Supply)
Spent Nuclear Fuel Litigation
In May 2011, PPL Susquehanna entered into a settlement agreement with the U.S. Government relating to PPL Susquehanna's lawsuit, seeking damages for the Department of Energy's failure to accept spent nuclear fuel from the PPL Susquehanna plant. PPL Susquehanna recorded credits totaling $56 million to "Fuel" on the Statement of Income in 2011 to recognize recovery, under the settlement agreement, of certain costs to store spent nuclear fuel at the Susquehanna plant. The amounts recorded through September 2011 cover costs incurred from 1998 through December 2010. PPL Susquehanna is eligible to receive payment of annual claims for allowed costs, as set forth in the settlement agreement, that are incurred through December 31, 2013. In exchange, PPL Susquehanna has waived any claims against the United States government for costs paid or injuries sustained related to storing spent nuclear fuel at the Susquehanna plant through December 31, 2013. In January 2014, PPL Susquehanna entered into a new agreement with the Department of Energy to extend the settlement agreement on the same terms as the prior agreement for an additional three years to the end of 2016.
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 impact 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 which are applicable to coal combustion wastes and by-products from facilities that generate electricity from coal in accordance with approved compliance plans. Costs not covered by the ECR mechanism for LG&E and KU and all such costs for PPL Electric are subject to rate recovery before the companies' respective state regulatory authorities, or the FERC, if applicable. Because PPL Electric does not own any generating plants, its exposure to related environmental compliance costs is reduced. As PPL Energy Supply is not a rate-regulated entity, it cannot seek to recover environmental compliance costs through the mechanism of rate recovery. 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.
(All Registrants except PPL Electric)
Air
CSAPR (formerly Clean Air Transport Rule) and CAIR
In July 2011, the EPA adopted the CSAPR. The CSAPR replaced the EPA's previous CAIR which was invalidated in July 2008 by the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit Court). CAIR subsequently was effectively reinstated by the D.C. Circuit Court in December 2008, pending finalization of the CSAPR. Like CAIR, CSAPR targeted sources in the eastern U.S. and would have required reductions in sulfur dioxide and nitrogen oxides in two phases (2012 and 2014).
In December 2011, the D.C. Circuit Court stayed implementation of the CSAPR and left CAIR in effect pending a final decision on the validity of the rule. In August 2012, the D.C. Circuit Court issued a ruling invalidating CSAPR, remanding the rule to the EPA for further action, and leaving CAIR in place during the interim. In June 2013, the U.S. Supreme Court granted the EPA's petition for review of the D.C. Circuit Court's August 2012 decision. Oral arguments before the U.S. Supreme Court were held in December 2013. Prior to a revised transport rule from the EPA, coal-fired generating plants could face tighter emission limitations on nitrogen oxides through state action.
The Kentucky fossil-fueled generating plants can meet the CAIR sulfur dioxide emission requirements by utilizing sulfur dioxide allowances (including banked allowances and optimizing existing controls). To meet standards for nitrogen oxides under the CAIR, the Kentucky companies will need to buy allowances and/or make operational changes. LG&E and KU do not currently anticipate that the costs of meeting these reinstated CAIR standards will be significant.
PPL Energy Supply's Pennsylvania fossil-fueled generating plants can meet the CAIR sulfur dioxide emission requirements with the existing scrubbers that were placed in service in 2008 and 2009. To meet the CAIR standards for nitrogen oxides, PPL Energy Supply will need to buy allowances and/or make operational changes, the costs of which are not anticipated to be significant.
National Ambient Air Quality Standards
PPL fossil-fueled generating plants may face further reductions in emissions as a result of more stringent national ambient air quality standards for ozone, nitrogen oxides, sulfur dioxide and/or fine particulates.
In 2010, the EPA finalized a new one-hour standard 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 Yellowstone County in Montana (Billings area) and part of Jefferson County in Kentucky. Attainment must be achieved by 2018. States are working on designations for other areas.
In December 2012, the EPA issued final rules that strengthen the fine particulate standards. Under the final rules, states and the EPA have until 2015 to identify non-attainment areas, and states have until 2020 to achieve attainment for those areas.
PPL, PPL Energy Supply, LKE, LG&E and KU anticipate that some of the measures required for compliance with the CAIR, or the MATS, or the Regional Haze requirements (as discussed below), such as upgraded or new sulfur dioxide scrubbers at certain plants and, in the case of LG&E and KU, the previously announced retirement of coal-fired generating units at the Cane Run, Green River and Tyrone plants, will help to achieve compliance with the new one-hour sulfur dioxide standard. If additional reductions were to be required, the financial impact could be significant. The short-term impact on the Corette plant from the EPA's final designation of part of Yellowstone County in Montana as non-attainment (as noted above) is not expected to be significant, as PPL Energy Supply previously announced its intent to place the plant in long-term reserve status beginning in April 2015.
Until particulate matter and sulfur dioxide maintenance and compliance plans are developed by the EPA and state or local agencies, including identification and finalization of attainment designations for particulate matter, PPL, PPL Energy Supply, LKE, LG&E and KU cannot predict the impact of the new standards.
MATS
In May 2011, the EPA published a proposed regulation requiring stringent reductions of mercury and other hazardous air pollutants from power plants. In February 2012, the EPA published the final rule, known as the MATS, with an effective date of April 2012. The rule is being challenged by industry groups and states in the D.C. Circuit Court, where oral arguments were held in December 2013. The rule provides for a three-year compliance deadline with the potential for a one-year extension as provided under the statute. PPL has received compliance extensions for certain plants in Kentucky and Pennsylvania. LG&E, KU and PPL Energy Supply are considering extension requests for other plants as well.
At the time the MATS rule was proposed, LG&E and KU filed requests with the KPSC for environmental cost recovery based on their expected need to install environmental controls including chemical additive and fabric-filter baghouses to remove air pollutants. Recovery of the cost of certain controls was granted by the KPSC in December 2011. LG&E's and KU's anticipated retirement of certain coal-fired electricity generating units located at Cane Run and Green River is in response to MATS and other environmental regulations. LG&E and KU are continuing to assess whether any revisions of their approved compliance plans will be necessary.
With respect to PPL Energy Supply's Pennsylvania plants, PPL Energy Supply believes that installation of chemical additive systems may be necessary at certain coal-fired plants, the capital cost of which is not expected to be significant. PPL Energy Supply continues to analyze the potential impact of MATS on operating costs. With respect to PPL Energy Supply's Montana plants, modifications to the air pollution controls installed on Colstrip may be required, the cost of which is not expected to be significant. For the Corette plant, PPL Energy Supply announced in September 2012 its intention, beginning in April 2015, to place the plant in long-term reserve status, suspending the plant's operation due to expected market conditions and the costs to comply with the MATS requirements. The Corette plant was determined to be impaired in December 2013. See Note 18 for additional information. PPL Energy Supply, LG&E and KU are continuing to conduct in-depth reviews of the MATS, including the potential implications to scrubber wastewater discharges. See the discussion of effluent limitations guidelines and standards below.
Regional Haze and Visibility
The EPA's regional haze programs were developed under the Clean Air Act to eliminate man-made visibility degradation by 2064. Under the programs, states are required to take action via state plans to make reasonable progress every decade, including the application of Best Available Retrofit Technology (BART) on power plants commissioned between 1962 and 1977.
The primary power plant emissions affecting visibility are sulfur dioxide, nitrogen oxides and particulates. To date, the focus of regional haze activity has been the western U.S. because the EPA had determined that the regional trading program in the eastern U.S. under CSAPR satisfied BART requirements to reduce sulfur dioxide and nitrogen oxides. However, the D.C. Circuit Court's August 2012 decision to vacate and remand CSAPR and to implement CAIR in its place on an interim basis leaves power plants located in the eastern U.S., including PPL's plants in Pennsylvania and Kentucky, exposed to reductions in sulfur dioxide and nitrogen oxides as required by BART, unless the D.C. Circuit Court's decision, now pending before the U.S. Supreme Court, is overturned.
In addition to this exposure stemming from the remand of CSAPR, LG&E's Mill Creek Units 3 and 4 are required to reduce sulfuric acid mist emissions because they were determined to have a significant regional haze impact. These reductions are in the Kentucky Division of Air Quality's regional haze state implementation plan that was submitted to the EPA. LG&E is currently installing sorbent injection technology to comply with these reductions, the costs of which are not expected to be significant.
In Montana, the EPA Region 8 developed the regional haze plan as the MDEQ declined to develop a BART state implementation plan. The EPA finalized the plan ("Federal Implementation Plan" or "FIP") in 2012. The final FIP assumed no additional controls for Corette or Colstrip Units 3 and 4, but proposed tighter limits for Corette and Colstrip Units 1 and 2. PPL Energy Supply expects to meet these tighter permit limits at Corette without any significant changes to operations, although other requirements have led to the planned suspension of operations at Corette beginning in April 2015 (see "MATS" above). Under the final FIP, Colstrip Units 1 and 2 may require additional controls, including the possible installation of an SNCR and other technology, to meet more stringent nitrogen oxides and sulfur dioxide limits. The cost of these potential additional controls, if required, could be significant. Both PPL and environmental groups have appealed the final FIP rules to the U.S. Court of Appeals for the Ninth Circuit.
New Source Review (NSR)
The EPA has continued its NSR enforcement efforts targeting coal-fired generating plants. The EPA has asserted that modification of these plants has increased their emissions and, consequently, that they are subject to stringent NSR requirements under the Clean Air Act. In April 2009, PPL received EPA information requests for its Montour and Brunner Island plants, and PPL and the EPA have exchanged certain information regarding this matter. In January 2009, PPL, PPL Energy Supply and other companies that own or operate the Keystone plant in Pennsylvania received a notice of violation from the EPA alleging that certain projects were undertaken without proper NSR compliance. In May and November 2012, PPL Montana received information requests from the EPA regarding projects undertaken during a Spring 2012 maintenance outage at Colstrip Unit 1. In September 2012, PPL Montana received an information request from the Montana Department of Environmental Quality regarding Colstrip Unit 1 and other projects. PPL and PPL Energy Supply cannot predict the outcome of these matters, and cannot estimate a range of reasonably possible losses, if any.
In March 2009, KU received an EPA notice alleging that KU violated certain provisions of the Clean Air Act's rules governing NSR and prevention of significant deterioration by installing sulfur dioxide scrubbers and SCR controls at its Ghent plant without assessing potential increased sulfuric acid mist emissions. KU contends that the projects in question were pollution control projects, and therefore exempt from the requirements cited by the EPA. In December 2009, the EPA issued an information request on this matter. In September 2012, the parties reached a tentative settlement addressing the Ghent NSR matter that seeks to resolve a September 2007 notice of violation alleging opacity violations at the plant. The parties subsequently entered into a consent decree which was approved by the court on September 11, 2013. The consent decree requires the incurrence of non-material costs that have already been accrued.
In August 2007, LG&E received information requests for the Mill Creek and Trimble County plants, and KU received requests for the Ghent plant, but they have received no further communications from the EPA since providing their responses. PPL, LKE, LG&E and KU cannot predict the outcome of these matters, and cannot estimate a range of reasonably possible losses, if any.
States and environmental groups also have commenced litigation alleging violations of the NSR regulations by coal-fired generating plants across the nation. See "Legal Matters" above for information on a lawsuit filed by environmental groups in March 2013 against PPL Montana and other owners of Colstrip.
If PPL subsidiaries are found to have violated NSR regulations by significantly increasing pollutants through a major plant modification, PPL, PPL Energy Supply, LKE, LG&E and KU would, among other things, be required to meet stringent permit limits reflecting Best Available Control Technology (BACT) for pollutants meeting the National Ambient Air Quality Standards (NAAQS) in the area and reflecting Lowest Achievable Emission Rates (LAER) for pollutants not meeting the NAAQS in the area. The costs to meet such limits, including installation of technology at certain units, could be significant.
TC2 Air Permit (PPL, LKE, LG&E and KU)
The Sierra Club and other environmental groups petitioned the Kentucky Environmental and Public Protection Cabinet to overturn the air permit issued for the TC2 baseload generating unit, but the agency upheld the permit in an order issued in September 2007. In response to subsequent petitions by environmental 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 KDAQ. In March 2010, the environmental groups petitioned the EPA 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 capital costs of this project, if any.
Cane Run Environmental Claims (PPL, LKE and LG&E)
In the 2011 to 2013 time period, the Louisville Metro Air Pollution Control District issued several notices of violation alleging violations of local air quality rules at the Cane Run plant. In November 2013, LG&E entered into a settlement resolving the pending citations in return for payment of a civil penalty in a non-material amount and performance of remedial measures not expected to result in material costs.
On September 6, 2013, PPL, LKE and LG&E received a letter on behalf of two residents adjacent to the Cane Run plant notifying various federal, state, and local agencies of their intent to file a citizen suit for alleged violations of the Clean Air Act (CAA) and Resource Conservation and Recovery Act (RCRA). On December 16, 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 for alleged violations of the CAA and RCRA. In addition, these plaintiffs assert common law claims of nuisance, trespass, and negligence. These plaintiffs seek injunctive relief and civil penalties that would accrue to governmental agencies, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the plant. In their individual capacities, these plaintiffs seek compensation for alleged adverse health effects. PPL, LKE and LG&E cannot predict the outcome of this matter or the potential impact on operations of the Cane Run plant. LG&E has previously announced that it anticipates retiring the coal-fired units at Cane Run before the end of 2015.
(All Registrants)
GHG Regulations and Tort Litigation
As a result of the April 2007 U.S. Supreme Court decision that the EPA has authority under the Clean Air Act to regulate GHG emissions from new motor vehicles, in April 2010, the EPA and the U.S. Department of Transportation issued new light-duty vehicle emissions standards that applied beginning with 2012 model year vehicles. The EPA also clarified that this standard, beginning in 2011, authorized regulation of GHG emissions from stationary sources under the NSR and Title V operating permit provisions of the Clean Air Act. As a result, any new sources or major modifications to existing GHG sources causing a net significant emissions increase now require adherence to the BACT permit limits for GHGs. The rules were challenged, and in June 2012 the D.C. Circuit Court upheld the EPA's regulations. In December 2012, the D.C. Circuit Court denied petitions for rehearing pertaining to its June 2012 opinion. On October 15, 2013, the U.S. Supreme Court granted certiorari for several petitions to decide whether the NSR provisions of the Clean Air Act require the EPA to regulate GHG emissions from stationary sources, such as power plants.
In June 2013, President Obama released his Climate Action Plan which reiterates the goal of reducing greenhouse gas emissions in the U.S. "in the range of" 17% below 2005 levels by 2020 through such actions as regulating power plant emissions, promoting increased use of renewables and clean energy technology, and establishing tighter energy efficiency standards. Also, by Presidential Memorandum the EPA was directed to issue a revised proposal for new power plants (a prior proposal was issued in 2012) by September 20, 2013, with a final rule in a timely fashion thereafter, and to issue proposed standards for existing plants by June 1, 2014 with a final rule to be issued by June 1, 2015. The EPA was further directed to require that states develop implementation plans for existing plants by June 2016. Regulation of existing plants could have a significant industry-wide impact depending on the structure and stringency of the final rule and the state implementation plans. The Administration's recent increase in its estimate of the "social cost of carbon" (which is used to calculate benefits associated with proposed regulations) from $23.80 to $38 per metric ton in 2015 may also lead to more costly regulatory requirements; the White House Office of Management and Budget (OMB) has opened this issue for public comment. Additionally, the Climate Action Plan requirements related to preparing the U.S. for the impacts of climate change could affect PPL and others in the industry as modifications to electricity delivery systems to improve the ability to withstand major storms may be needed in order to meet those requirements.
The EPA issued its revised proposal for new sources on September 20, 2013 as directed by the White House. This proposal was published in the Federal Register on January 8, 2014, with comments due on March 10, 2014. Unlike the EPA's prior proposal, the EPA's revised proposal established separate emission standards for coal and 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 revised proposal effectively precludes the construction of new coal plants. The EPA proposed the same standard for NGCC power plants as was proposed in 2012 and may not be consistently achievable. In addition, the EPA deleted the explicit exemption previously proposed for simple-cycle natural gas plants.
At the regional level, ten northeastern states have been participating in a cap-and-trade program called the Regional Greenhouse Gas Initiative (RGGI). The program commenced in January 2009 and covers electric power plants greater than 25 MW. The program calls for a 10% reduction in carbon dioxide emissions from these plants by 2019 compared to 2005 levels. Pennsylvania has not stated an intention to join the RGGI, but enacted the Pennsylvania Climate Change Act of 2008 (PCCA). The PCCA established a Climate Change Advisory Committee to advise the PADEP on the development of a Climate Change Action Plan. In December 2013, the Advisory Committee issued an updated Climate Change Action Report and identified specific actions that could result in reducing GHG emissions by 30% by 2020. The report recognized some legislative initiatives that were enacted since 2009 that facilitated reductions in GHG emissions and made a number of legislative recommendations that include amending the PA AEPS Act to include additional waste-to-energy facilities, providing incentives for coal mine methane usage, providing incentives for alternative fuel vehicles and addressing the long-term viability issues of carbon capture and sequestration.
In November 2008, the Governor of Kentucky issued a comprehensive energy plan including non-binding targets aimed at promoting improved energy efficiency, development of alternative energy, development of carbon capture and sequestration projects, and other actions to reduce GHG emissions.  In December 2009, the Kentucky Climate Action Plan Council was established to develop an action plan addressing potential GHG reductions and related measures.  In November 2011, the Council issued a final report to the Secretary of Kentucky's Energy and Environment Cabinet for his consideration.  The final report acknowledged that the recommendations would require additional review and analysis prior to implementation, and that many of the recommendations would likely require, in part, further legislative or regulatory actions.  The impact of any such plan is not now determinable, but the costs to comply with the plan could be significant.
A number of lawsuits have been filed asserting common law claims including nuisance, trespass and negligence against various companies with GHG emitting plants and, although the decided cases to date have not sustained claims brought on the basis of these theories of liability, the law remains unsettled on these claims. In September 2009, the U.S. Court of Appeals for the Second Circuit in the case of AEP v. Connecticut reversed a federal district court's decision and ruled that several states and public interest groups, as well as the City of New York, could sue five electric utility companies under federal common law for allegedly causing a public nuisance as a result of their emissions of GHGs. In June 2011, the U.S. Supreme Court overturned the Second Circuit and held that such federal common law claims were displaced by the Clean Air Act and regulatory actions of the EPA. In addition, in Comer v. Murphy Oil (Comer case), the U.S. Court of Appeals for the Fifth Circuit (Fifth Circuit) declined to overturn a district court ruling that plaintiffs did not have standing to pursue state common law claims against companies that emit GHGs. The complaint in the Comer case named the previous indirect parent of LKE as a defendant based upon emissions from the Kentucky plants. In January 2011, the Supreme Court denied a petition to reverse the Fifth Circuit's ruling. In May 2011, the plaintiffs in the Comer case filed a substantially similar complaint in federal district court in Mississippi against 87 companies, including KU and three other indirect subsidiaries of LKE, under a Mississippi statute that allows the re-filing of an action in certain circumstances. In March 2012, the Mississippi federal district court granted defendants' motions to dismiss the state common law claims. Plaintiffs appealed to the U.S. Court of Appeals for the Fifth Circuit, and in May 2013, the Fifth Circuit affirmed the district court's dismissal of the case. Additional litigation in federal and state courts over such issues is continuing. PPL, LKE and KU cannot predict the outcome of these lawsuits or estimate a range of reasonably possible losses, if any.
In 2013, PPL's power plants emitted approximately 62 million tons of carbon dioxide compared with 70 million tons in 2012. The totals reflect 26 million tons from PPL Energy Supply, and 17 million tons and 19 million tons from LG&E's and KU's generating fleets. All tons are U.S. short tons (2,000 pounds/ton).
Renewable Energy Legislation (All Registrants)
There has been interest in renewable energy legislation at both the state and federal levels. Federal legislation on renewable energy is not expected to be enacted this year. In Pennsylvania, bills were introduced calling for an increase in AEPS Tier 1 obligations and to create a $25 million permanent funding program for solar generation. Bills (SB 1171 and HB 100) were also introduced to add natural gas as a qualified AEPS resource, and another bill (HB 1912) would repeal the AEPS Act entirely. A bill adding new hydropower to Montana's renewable portfolio standard was enacted with an effective date of October 1, 2013. An interim legislative committee in Montana is reviewing the state's RPS. PPL and PPL Energy Supply cannot predict at this time whether the committee will recommend any changes to existing laws. In Maryland, bills have been introduced in the 2014 session to double the state's RPS requirement from 20% to 40% and provide exceptions for specific types of energy sources.
The Registrants believe there are financial, regulatory and logistical uncertainties related to the implementation of renewable energy mandates that will need to be resolved before the impact of such requirements on them can be estimated. Such uncertainties, among others, include the need to provide back-up supply to augment intermittent renewable generation, potential generation over-supply and downward pressure on energy prices that could result from such renewable generation and back-up, impacts to PJM's capacity market and the need for substantial changes to transmission and distribution systems to accommodate renewable energy sources. These uncertainties are not directly addressed by proposed legislation. PPL and PPL Energy Supply cannot predict at this time the effect on their competitive plants' future competitive position, results of operation, cash flows and financial position of renewable energy mandates that may be adopted, although the costs to implement and comply with any such requirements could be significant.
Water/Waste
Coal Combustion Residuals (CCRs) (All Registrants except PPL Electric)
In June 2010, the EPA proposed two approaches to regulating the disposal and management of CCRs (as either hazardous or non-hazardous) under the Resource Conservation and Recovery Act (RCRA). CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes. Regulating CCRs as a hazardous waste under Subtitle C of the RCRA would materially increase costs and result in early retirements of many coal-fired plants, as it would require plants to retrofit their operations to comply with full hazardous waste requirements for the generation of CCRs and associated waste waters through generation, transportation and disposal. This would also have a negative impact on the beneficial use of CCRs and could eliminate existing markets for CCRs. The EPA's proposed approach to regulate CCRs as non-hazardous waste under Subtitle D of the RCRA would mainly affect disposal and most significantly affect any wet disposal operations. Under this approach, many of the current markets for beneficial uses would not be affected. Currently, PPL expects that several of its plants in Kentucky and Montana could be significantly impacted by the EPA's proposed non-hazardous waste regulations, as these plants are using surface impoundments for management and disposal of CCRs.
The EPA has issued information requests on CCR management practices at numerous plants throughout the power industry as it considers whether or not to regulate CCRs as hazardous waste. PPL has provided information on CCR management practices at most of its plants in response to the EPA's requests. In addition, the EPA has conducted follow-up inspections to evaluate the structural stability of CCR management facilities at several PPL plants and PPL has implemented or is implementing certain actions in response to recommendations from these inspections.
The EPA is continuing to evaluate the unprecedented number of comments it received on its June 2010 proposed regulations. In October 2011, the EPA issued a Notice of Data Availability (NODA) requesting comments on selected documents it received during the comment period for the proposed regulations. On September 20, 2013, in response to the proposed Effluent Limitation Guidelines, PPL submitted comments on the proposed CCR regulations. Also, on September 3, 2013, PPL commented on a second CCR NODA seeking comment on additional information related to the EPA's proposal.
A coalition of environmental groups and two CCR recycling companies have filed lawsuits against the EPA seeking a deadline for final rulemaking and, in settlement of that litigation, the EPA has agreed to issue its final rulemaking by the end of 2014.
In July 2013, the U.S. House of Representatives passed House Bill H.R. 2218, the Coal Residuals and Reuse Management Act of 2013, which would preempt the EPA from issuing final CCR regulations and would set non-hazardous CCR standards under RCRA and authorize state permit programs. It remains uncertain whether similar legislation will likely be passed by the U.S. Senate. PPL, PPL Energy Supply, LKE, LG&E and KU cannot predict at this time the final requirements of the EPA's CCR regulations or potential changes to the RCRA and what impact they would have on their facilities, but the financial and operational impact is expected to be material if CCRs are regulated as hazardous waste and significant if regulated as non-hazardous.
Trimble County Landfill Permit (PPL, LKE, LG&E and KU)
In May 2011, LG&E submitted an application for a special waste landfill permit to handle coal combustion residuals generated at the Trimble County plant. After extensive review of the permit application in May 2013, the Kentucky Division of Waste Management denied the permit application on the grounds that the proposed facility would violate the Kentucky Cave Protection Act because it would eliminate an on-site karst feature considered to be a cave. After assessing additional options for managing coal combustion residuals, in January 2014, LG&E submitted to the Kentucky Division of Waste Management a landfill permit application for an alternate site adjacent to the plant. PPL, LKE, LG&E and KU are unable to determine the precise impact of this matter until a landfill permit is issued and any resulting legal challenges are concluded.
Seepages and Groundwater Infiltration – Pennsylvania, Montana and Kentucky
(All Registrants except PPL Electric)
Seepages or groundwater infiltration have been detected at active and retired wastewater basins and landfills at various PPL, PPL Energy Supply, LKE, LG&E and KU plants. PPL, PPL Energy Supply, LKE, LG&E and KU have completed or are completing assessments of seepages or groundwater infiltration at various facilities and have completed or are working with agencies to implement assessment or abatement measures, where required. A range of reasonably possible losses cannot currently be estimated.
(PPL and PPL Energy Supply)
In August 2012, PPL Montana entered into an Administrative Order on Consent (AOC) with the MDEQ which establishes a comprehensive process to investigate and remediate groundwater seepage impacts related to the wastewater facilities at the Colstrip power plant. The AOC requires that within five years, PPL Montana provide financial assurance to the MDEQ for the costs associated with closure and future monitoring of the waste-water treatment facilities. PPL Montana cannot predict at this time if the actions required under the AOC will create the need to adjust the existing ARO related to these facilities.
In September 2012, Earthjustice filed an affidavit pursuant to Montana's Major Facility Siting Act (MFSA) that sought review of the AOC by Montana's Board of Environmental Review (BER) on behalf of the Sierra Club, the MEIC, and the National Wildlife Federation (NWF). In September 2012, PPL Montana filed an election with the BER to have this proceeding conducted in Montana state district court as contemplated by the MFSA. In October 2012, Earthjustice filed a petition for review of the AOC in the Montana state district court in Rosebud County.
(All Registrants except PPL Electric)
Clean Water Act 316(b)
The EPA published proposed rule 316(b) for existing facilities in April 2011. The EPA has been evaluating the comments it received to the proposed rule and meeting with industry groups to discuss options. The proposed rule contains two requirements to reduce impact to aquatic organisms at cooling water intake structures. The first requires all existing facilities to meet standards for the reduction of mortality of aquatic organisms that become trapped against water intake screens (impingement) regardless of the levels of mortality actually occurring or the cost to achieve the standards. The second requirement is to determine and install the best technology available to reduce mortality of aquatic organisms pulled through a plant's cooling water system (entrainment). A form of cost-benefit analysis is allowed for this second requirement involving a site-specific evaluation based on nine factors, including impacts to energy delivery reliability and the remaining useful life of the plant. The final rule is expected by April 17, 2014. Until the final rule is issued, PPL, PPL Energy Supply, LKE, LG&E and KU cannot estimate a range of reasonably possible costs, if any, that would be required to comply with such a regulation.
Effluent Limitations Guidelines (ELGs) and Standards
In June 2013, the EPA published proposed regulations to revise discharge limitations for steam electric generation wastewater permits. The proposed limitations are based on the EPA review of available treatment technologies and their capacity for reducing pollutants and include new requirements for fly ash and bottom ash transport water and metal cleaning waste waters, as well as new limits for scrubber wastewater and landfill leachate. The EPA's proposed ELG regulations contain requirements that would affect the inspection and operation of CCR facilities, if finalized. The EPA has indicated that it will coordinate these regulations with the regulation of CCRs discussed above. The proposal contains alternative approaches, some of which could significantly impact PPL's coal-fired plants. PPL, PPL Energy Supply, LKE, LG&E and KU worked with industry groups to comment on the proposed regulation on September 20, 2013. The final regulation is expected to be issued in May 2014 but it may be delayed. At the present time, PPL, PPL Energy Supply, LKE, LG&E and KU are unable to predict the outcome of this matter or estimate a range of reasonably possible costs, but the costs could be significant. Pending finalization of the ELGs, certain states and environmental groups (including Pennsylvania and Kentucky) are proposing more stringent technology-based limits in permit renewals. Depending on the final limits imposed, the costs of compliance could be significant and costs could be imposed ahead of federal timelines.
Other Issues
The EPA is reassessing its polychlorinated 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 is planning to propose the revised regulations in November 2014. PCBs are found, in varying degrees, in all of the Registrants' operations. The Registrants cannot predict at this time the outcome of these proposed EPA regulations and what impact, if any, they would have on their facilities, but the costs could be significant.
PPL Energy Supply has investigated alternatives to exclude fish from the discharge channel at its Brunner Island plant, but the subsidiary and the PADEP have concluded that a barrier method to exclude fish is not workable. In June 2012, a Consent Order and Agreement (COA) was signed that allows the subsidiary to study a change in a cooling tower operational method that may keep fish from entering the channel. Should this approach fail, the COA requires a retrofit of impingement control technology at the intakes to the cooling towers, the cost of which could be significant.
In May 2010, the Kentucky Waterways Alliance and other environmental groups filed a petition with the Kentucky Energy and Environment Cabinet 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 Cabinet issued a final order upholding the permit. In December 2010, the environmental groups appealed the order to the Trimble Circuit Court, but the case was subsequently transferred to the Franklin Circuit Court. In September 2013, the court reversed the Cabinet order upholding the permit and remanded the permit to the agency for further proceedings. In October 2013, LG&E filed a notice of appeal with the Kentucky Court of Appeals. PPL, LKE, LG&E and KU are unable to predict the outcome of this matter or estimate a range of reasonably possible losses, if any.
The EPA and the Army Corps of Engineers are working on a guidance document that will expand the federal government's interpretation of what constitutes "waters of the U.S." subject to regulation under the Clean Water Act. This change has the potential to affect generation and delivery operations, with the most significant effect being the potential elimination of the existing regulatory exemption for plant waste water treatment systems. The costs that may be imposed on the Registrants as a result of any eventual expansion of this interpretation cannot reliably be estimated at this time but 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 Columbia Gas Plant site, the Metal Bank site and the Ward Transformer 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. However, should the EPA require different or additional measures in the future, 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 remediating or have completed the remediation of several sites that were not addressed under a regulatory program such as Superfund, but for which PPL Electric, LG&E and KU may be liable for remediation. These include a number of former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operated or currently owned by predecessors or affiliates of PPL Electric, LG&E and KU. There are additional sites, formerly owned or operated by PPL Electric, LG&E and KU predecessors or affiliates, for which PPL Electric, LG&E and KU lack information on current site conditions and are therefore unable to predict what, if any, potential liability they may have.
Depending on the outcome of investigations at sites where investigations have not begun or been completed or developments at sites for which PPL Electric, LG&E and KU currently lack information, the costs of remediation and other liabilities could be material. PPL, PPL Electric, LKE, LG&E and KU cannot estimate a range of reasonably possible losses, if any, related to these matters.
The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result of the EPA's evaluation, individual states may establish stricter standards for water quality and soil cleanup. This could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. PPL, PPL Electric, LKE, LG&E and KU cannot estimate a range of reasonably possible losses, if any, related to these matters.
Under the Pennsylvania Clean Streams Law, subsidiaries of PPL Generation are obligated to remediate acid mine drainage at former mine sites and may be required to take additional steps to prevent potential acid mine drainage at previously capped refuse piles. One PPL Generation subsidiary is pumping mine water at two mine sites and treating water at one of these sites. Another PPL Generation subsidiary has installed a passive wetlands treatment system at a third site. In December 2013, PPL Generation subsidiaries reached an agreement of sale for one of the two pumping mine sites and the passive wetlands treatment system at the third site. Once these sales are finalized and responsibilities are transferred to the new owner, subject to regulatory agency approvals, PPL Generation subsidiaries will no longer be responsible for operating and maintaining these two sites. At December 31, 2013, PPL Energy Supply had accrued a discounted liability of $21 million to cover the costs of pumping and treating groundwater at the two mine sites for 50 years and for operating and maintaining passive wetlands treatment at the third site. PPL Energy Supply discounted this liability based on risk-free rates at the time of the mine closures. The weighted-average rate used was 8.21%. Expected undiscounted payments are estimated at $1 million for each of the years from 2014 through 2018, and $107 million for work after 2018.
From time to time, PPL Energy Supply, PPL Electric, LG&E and KU undertake remedial action in response to spills or other releases at various on-site and off-site locations, negotiate with the EPA and state and local agencies regarding actions necessary for compliance with applicable requirements, negotiate with property owners and other third parties alleging impacts from PPL's operations and undertake similar actions necessary to resolve environmental matters which 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 these Registrants' operations.
Future cleanup or remediation work at sites currently under review, or at sites not currently identified, may result in significant additional costs for the Registrants.
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
Nuclear Insurance (PPL and PPL Energy Supply)
The Price-Anderson Act is a United States Federal law which governs liability-related issues and ensures the availability of funds for public liability claims arising from an incident at any of the U.S. licensed nuclear facilities. It also seeks to limit the liability of nuclear reactor owners for such claims from any single incident. Effective September 10, 2013, the liability limit per incident was $13.6 billion for such claims which is funded by insurance coverage from American Nuclear Insurers (ANI) and an industry assessment program.
Under the industry assessment program, in the event of a nuclear incident at any of the reactors covered by The Price-Anderson Act as amended, PPL Susquehanna could be assessed up to $255 million per incident, payable at $38 million per year.
Additionally, PPL Susquehanna purchases property insurance programs from NEIL, an industry mutual insurance company of which PPL Susquehanna is a member. Effective April 1, 2013, facilities at the Susquehanna plant are insured against property damage losses up to $2.50 billion. PPL Susquehanna also purchases an insurance program that provides coverage for the cost of replacement power during prolonged outages of nuclear units caused by certain specified conditions.
Under the NEIL property and replacement power insurance programs, PPL Susquehanna could be assessed retrospective premiums in the event of the insurers' adverse loss experience. Effective April 1, 2013, this maximum assessment was $46 million.
Labor Unions (All Registrants)
In 2014, certain labor agreement negotiations are scheduled to begin or have begun. For PPL, PPL Energy Supply and PPL Electric, negotiations with the IBEW commenced in January 2014. The current agreement expires in May 2014. For LG&E, negotiations with the IBEW will begin in October 2014. The current agreement expires in November 2014. For KU, the agreement with the IBEW includes a wage reopener in July 2014 and the current agreement expires in August 2015. Additionally, KU's negotiations with the United Steelworkers of America labor union will begin in July 2014 and the current agreement expires in August 2014. The Registrants cannot predict the outcome of the union labor negotiations.
The labor agreements expiring in 2014 covered the following employees at December 31, 2013:
	Number of Employees		Percent of Total Workforce
PPL	3,755		20%
PPL Energy Supply	1,190		24%
PPL Electric	1,419		63%
LKE	774		22%
LG&E	701		70%
KU	73		7%
Guarantees and Other Assurances
(All Registrants)
In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Such agreements include, for example, guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage.
(PPL)
PPL fully and unconditionally guarantees all of the debt securities of PPL Capital Funding.
(All Registrants)
The table below details guarantees provided as of December 31, 2013. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance under each of these guarantees is remote except for "WPD guarantee of pension and other obligations of unconsolidated entities" and "Indemnification of lease termination and other divestitures." The total recorded liability at December 31, 2013 and 2012 was $26 million and $24 million for PPL and $19 million and $20 million for LKE. For reporting purposes, on a consolidated basis, all guarantees of PPL Energy Supply (other than the letters of credit), PPL Electric, LKE, LG&E and KU also apply to PPL, and all guarantees of LG&E and KU also apply to LKE.
		Exposure at				Expiration
		December 31, 2013				Date
PPL
Indemnifications related to the WPD Midlands acquisition				(a)
WPD indemnifications for entities in liquidation and sales of assets		$	12	(b)		2017 - 2018
WPD guarantee of pension and other obligations of unconsolidated entities			127	(c)
PPL Energy Supply
Letters of credit issued on behalf of affiliates			29	(d)		2014 - 2015
Indemnifications for sales of assets			250	(e)		2025
Guarantee of a portion of a divested unconsolidated entity's debt			22	(f)		2018
PPL Electric
Guarantee of inventory value			27	(g)		2017
LKE
Indemnification of lease termination and other divestitures			301	(h)		2021 - 2023
LG&E and KU
LG&E and KU guarantee of shortfall related to OVEC				(i)
(a)       Indemnifications related to certain liabilities, including a specific unresolved tax issue and those relating to properties and assets owned by the seller that were transferred to WPD Midlands in connection with the acquisition. A cross indemnity has been received from the seller on the tax issue. The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.
(b)       Indemnification to the liquidators and certain others for existing liabilities or expenses or liabilities arising during the liquidation process. The indemnifications are limited to distributions made from the subsidiary to its parent either prior or subsequent to liquidation or is 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 electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At December 31, 2013, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.
(d)       Standby letter of credit arrangements under PPL Energy Supply's credit facilities for the purposes of protecting various third parties against nonperformance by PPL. This is not a guarantee by PPL on a consolidated basis
(e)       Indemnifications are governed by the specific sales agreement and include breach of the representations, warranties and covenants, and liabilities for certain other matters. PPL Energy Supply's maximum exposure with respect to certain indemnifications and the expiration of the indemnifications cannot be estimated because the maximum potential liability is not capped by the transaction documents and the expiration date is based on the applicable statute of limitations. The exposure and expiration date noted is based on those cases in which the agreements provide for specific limits.
(f)       Relates to a guarantee of one-third of the divested entity's debt. The purchaser provided a cross-indemnity, secured by a lien on the purchaser's stock of the divested entity. The exposure noted reflects principal only.
(g)       A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold.
(h)       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 guarantees is the LKE guarantee covering operational, regulatory and environmental commitments 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 fall outside the cumulative cap. LKE has contested the applicability of the indemnification requirement relating to one matter presented by a counterparty under this guarantee. Another guarantee with a maximum exposure of $100 million covering other indemnifications expires in 2023. In May 2012, LKE's indemnitee received an arbitration panel's decision affecting this matter, which granted LKE's indemnitee certain rights of first refusal to purchase excess power at a market-based price rather than at an absolute fixed price. In January 2013, LKE's indemnitee commenced a proceeding in the Kentucky Court of Appeals appealing the December 2012 order of the Henderson Circuit Court, confirming the arbitration award. A decision in the appellate matter may occur during 2014. LKE believes its indemnification obligations in this matter remain subject to various uncertainties, including potential for additional legal challenges regarding the arbitration decision as well as future prices, availability and demand for the subject excess power. LKE continues to evaluate various legal and commercial options with respect to this indemnification matter. The ultimate outcomes of the WKE termination-related indemnifications cannot be predicted at this time. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum; however, LKE is not aware of formal claims under such indemnities made by any party at this time. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. In the second quarter of 2012, LKE adjusted its estimated liability for certain of these indemnifications by $9 million ($5 million after-tax), which is reflected in "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statement of Income. The adjustment was recorded in the Kentucky Regulated segment for PPL. LKE cannot predict the ultimate outcomes of such indemnification circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded.
(i)       Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts currently included within a demand charge designed to cover these costs over the term of the contract. LKE's proportionate share of OVEC's outstanding debt was $129 million at December 31, 2013, consisting of LG&E's share of $89 million and KU's share of $40 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchases Commitments" above for additional information on the OVEC power purchase contract.
The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is remote.
PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $225 million. This insurance may be applicable to obligations under certain of these contractual arrangements.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
PPL Energy Supply LLC [Member]	'
Related Party Transactions [Line Items]	'
Related Party Transactions	'
	16. Related Party Transactions
	PLR Contracts/Purchase of Accounts Receivable (PPL Energy Supply and PPL Electric)
	PPL Electric holds competitive solicitations for PLR generating supply. PPL EnergyPlus has been awarded a portion of the PLR generation supply through these competitive solicitations. The sales and purchases between PPL EnergyPlus and PPL Electric are included in the Statements of Income as "Unregulated wholesale energy to affiliate" by PPL Energy Supply and as "Energy purchases from affiliate" by PPL Electric.
	Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all suppliers to post collateral once credit exposures exceed defined credit limits. PPL EnergyPlus is required to post collateral with PPL Electric: (a) when the market price of electricity to be delivered by PPL EnergyPlus exceeds the contract price for the forecasted quantity of electricity to be delivered and (b) this market price exposure exceeds a contractual credit limit. Based on the current credit rating of PPL Energy Supply, as guarantor, PPL EnergyPlus' credit limit was $20 million at December 31, 2013. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts.
	PPL Electric'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 PPL EnergyPlus.
	At December 31, 2013, PPL Energy Supply had a net credit exposure of $28 million from PPL Electric from its commitment as a PLR supplier and from the sale of its accounts receivable to PPL Electric.
	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. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation.
	Support Costs (All Registrants except PPL)
	Both PPL Services and LKS provide the respective PPL and LKE subsidiaries with administrative, management and support services. Where applicable, the costs of these services are charged to the respective subsidiaries as direct support costs. General costs that cannot be directly attributed to a specific subsidiary are allocated and charged to the respective subsidiaries as indirect support costs. PPL Services uses a three-factor methodology that includes the subsidiaries' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
	LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.
	Intercompany Borrowings
	(PPL Energy Supply)
	A PPL Energy Supply subsidiary periodically holds revolving lines of credit and demand notes from certain affiliates. No balance was outstanding at December 31, 2013 and 2012. Interest earned on these revolving facilities is included in "Interest Income from Affiliates" on the Statement of Income. Interest earned on borrowings was not significant for 2013 and 2012. For 2011, interest earned on borrowings was $8 million, which was primarily attributable to borrowings by PPL Energy Funding with an interest rate of 3.77%.
	(PPL Electric)
	A PPL Electric subsidiary periodically holds revolving demand notes from certain affiliates. At December 31, 2013, $150 million was outstanding and was reflected in “Notes receivable from affiliate” on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013, was 1.92%. Interest earned on these revolving facilities was not significant for 2013, 2012 and 2011.
	(LKE)
	LKE maintains a revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. In October 2013, the revolving line of credit was reduced by $75 million and the limit as of December 31, 2013 was $225 million. The interest rates on borrowings are equal to one-month LIBOR plus a spread. No balance was outstanding at December 31, 2013. At December 31, 2012, $25 million was outstanding and was reflected in "Notes payable with affiliates" on the Balance Sheet. The interest rate on the outstanding borrowing at December 31, 2012 was 1.71%. Interest on the revolving line of credit was not significant for 2013 or 2012.
	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. At December 31, 2013, $70 million was outstanding and was reflected in "Notes receivable from affiliates" on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013 was 2.17%. Interest income on this note was not significant for 2013 or 2012.
	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 19 for additional information on intercompany derivatives.
	(PPL Energy Supply)
	Trademark Royalties
	A PPL subsidiary owned PPL trademarks and billed certain affiliates for their use under a licensing agreement. This agreement was terminated in December 2011. PPL Energy Supply was charged $40 million of license fees in 2011. These charges were primarily included in "Other operation and maintenance" on the Statement of Income.
	Distribution of Interest in PPL Global to Parent
	In January 2011, PPL Energy Supply distributed its membership interest in PPL Global to its parent, PPL Energy Funding. See Note 9 for additional information.
	Other (All Registrants except PPL)
	See Note 1 for discussions regarding the intercompany tax sharing agreement and Note 7 for a discussion regarding capital transactions by PPL Energy Supply, PPL Electric, LKE, LG&E and KU. For PPL Energy Supply, PPL Electric and LKE, see Note 1 for discussions regarding intercompany allocations of stock-based compensation expense. For PPL Energy Supply, PPL Electric, LG&E and KU, see Note 13 for discussions regarding intercompany allocations associated with defined benefits.
PPL Electric Utilities Corp [Member]	'
Related Party Transactions [Line Items]	'
Related Party Transactions	'
	16. Related Party Transactions
	PLR Contracts/Purchase of Accounts Receivable (PPL Energy Supply and PPL Electric)
	PPL Electric holds competitive solicitations for PLR generating supply. PPL EnergyPlus has been awarded a portion of the PLR generation supply through these competitive solicitations. The sales and purchases between PPL EnergyPlus and PPL Electric are included in the Statements of Income as "Unregulated wholesale energy to affiliate" by PPL Energy Supply and as "Energy purchases from affiliate" by PPL Electric.
	Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all suppliers to post collateral once credit exposures exceed defined credit limits. PPL EnergyPlus is required to post collateral with PPL Electric: (a) when the market price of electricity to be delivered by PPL EnergyPlus exceeds the contract price for the forecasted quantity of electricity to be delivered and (b) this market price exposure exceeds a contractual credit limit. Based on the current credit rating of PPL Energy Supply, as guarantor, PPL EnergyPlus' credit limit was $20 million at December 31, 2013. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts.
	PPL Electric'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 PPL EnergyPlus.
	At December 31, 2013, PPL Energy Supply had a net credit exposure of $28 million from PPL Electric from its commitment as a PLR supplier and from the sale of its accounts receivable to PPL Electric.
	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. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation.
	Support Costs (All Registrants except PPL)
	Both PPL Services and LKS provide the respective PPL and LKE subsidiaries with administrative, management and support services. Where applicable, the costs of these services are charged to the respective subsidiaries as direct support costs. General costs that cannot be directly attributed to a specific subsidiary are allocated and charged to the respective subsidiaries as indirect support costs. PPL Services uses a three-factor methodology that includes the subsidiaries' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
	LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.
	Intercompany Borrowings
	(PPL Energy Supply)
	A PPL Energy Supply subsidiary periodically holds revolving lines of credit and demand notes from certain affiliates. No balance was outstanding at December 31, 2013 and 2012. Interest earned on these revolving facilities is included in "Interest Income from Affiliates" on the Statement of Income. Interest earned on borrowings was not significant for 2013 and 2012. For 2011, interest earned on borrowings was $8 million, which was primarily attributable to borrowings by PPL Energy Funding with an interest rate of 3.77%.
	(PPL Electric)
	A PPL Electric subsidiary periodically holds revolving demand notes from certain affiliates. At December 31, 2013, $150 million was outstanding and was reflected in “Notes receivable from affiliate” on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013, was 1.92%. Interest earned on these revolving facilities was not significant for 2013, 2012 and 2011.
	(LKE)
	LKE maintains a revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. In October 2013, the revolving line of credit was reduced by $75 million and the limit as of December 31, 2013 was $225 million. The interest rates on borrowings are equal to one-month LIBOR plus a spread. No balance was outstanding at December 31, 2013. At December 31, 2012, $25 million was outstanding and was reflected in "Notes payable with affiliates" on the Balance Sheet. The interest rate on the outstanding borrowing at December 31, 2012 was 1.71%. Interest on the revolving line of credit was not significant for 2013 or 2012.
	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. At December 31, 2013, $70 million was outstanding and was reflected in "Notes receivable from affiliates" on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013 was 2.17%. Interest income on this note was not significant for 2013 or 2012.
	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 19 for additional information on intercompany derivatives.
	(PPL Energy Supply)
	Trademark Royalties
	A PPL subsidiary owned PPL trademarks and billed certain affiliates for their use under a licensing agreement. This agreement was terminated in December 2011. PPL Energy Supply was charged $40 million of license fees in 2011. These charges were primarily included in "Other operation and maintenance" on the Statement of Income.
	Distribution of Interest in PPL Global to Parent
	In January 2011, PPL Energy Supply distributed its membership interest in PPL Global to its parent, PPL Energy Funding. See Note 9 for additional information.
	Other (All Registrants except PPL)
	See Note 1 for discussions regarding the intercompany tax sharing agreement and Note 7 for a discussion regarding capital transactions by PPL Energy Supply, PPL Electric, LKE, LG&E and KU. For PPL Energy Supply, PPL Electric and LKE, see Note 1 for discussions regarding intercompany allocations of stock-based compensation expense. For PPL Energy Supply, PPL Electric, LG&E and KU, see Note 13 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	'
	16. Related Party Transactions
	PLR Contracts/Purchase of Accounts Receivable (PPL Energy Supply and PPL Electric)
	PPL Electric holds competitive solicitations for PLR generating supply. PPL EnergyPlus has been awarded a portion of the PLR generation supply through these competitive solicitations. The sales and purchases between PPL EnergyPlus and PPL Electric are included in the Statements of Income as "Unregulated wholesale energy to affiliate" by PPL Energy Supply and as "Energy purchases from affiliate" by PPL Electric.
	Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all suppliers to post collateral once credit exposures exceed defined credit limits. PPL EnergyPlus is required to post collateral with PPL Electric: (a) when the market price of electricity to be delivered by PPL EnergyPlus exceeds the contract price for the forecasted quantity of electricity to be delivered and (b) this market price exposure exceeds a contractual credit limit. Based on the current credit rating of PPL Energy Supply, as guarantor, PPL EnergyPlus' credit limit was $20 million at December 31, 2013. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts.
	PPL Electric'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 PPL EnergyPlus.
	At December 31, 2013, PPL Energy Supply had a net credit exposure of $28 million from PPL Electric from its commitment as a PLR supplier and from the sale of its accounts receivable to PPL Electric.
	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. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation.
	Support Costs (All Registrants except PPL)
	Both PPL Services and LKS provide the respective PPL and LKE subsidiaries with administrative, management and support services. Where applicable, the costs of these services are charged to the respective subsidiaries as direct support costs. General costs that cannot be directly attributed to a specific subsidiary are allocated and charged to the respective subsidiaries as indirect support costs. PPL Services uses a three-factor methodology that includes the subsidiaries' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
	LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.
	Intercompany Borrowings
	(PPL Energy Supply)
	A PPL Energy Supply subsidiary periodically holds revolving lines of credit and demand notes from certain affiliates. No balance was outstanding at December 31, 2013 and 2012. Interest earned on these revolving facilities is included in "Interest Income from Affiliates" on the Statement of Income. Interest earned on borrowings was not significant for 2013 and 2012. For 2011, interest earned on borrowings was $8 million, which was primarily attributable to borrowings by PPL Energy Funding with an interest rate of 3.77%.
	(PPL Electric)
	A PPL Electric subsidiary periodically holds revolving demand notes from certain affiliates. At December 31, 2013, $150 million was outstanding and was reflected in “Notes receivable from affiliate” on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013, was 1.92%. Interest earned on these revolving facilities was not significant for 2013, 2012 and 2011.
	(LKE)
	LKE maintains a revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. In October 2013, the revolving line of credit was reduced by $75 million and the limit as of December 31, 2013 was $225 million. The interest rates on borrowings are equal to one-month LIBOR plus a spread. No balance was outstanding at December 31, 2013. At December 31, 2012, $25 million was outstanding and was reflected in "Notes payable with affiliates" on the Balance Sheet. The interest rate on the outstanding borrowing at December 31, 2012 was 1.71%. Interest on the revolving line of credit was not significant for 2013 or 2012.
	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. At December 31, 2013, $70 million was outstanding and was reflected in "Notes receivable from affiliates" on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013 was 2.17%. Interest income on this note was not significant for 2013 or 2012.
	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 19 for additional information on intercompany derivatives.
	(PPL Energy Supply)
	Trademark Royalties
	A PPL subsidiary owned PPL trademarks and billed certain affiliates for their use under a licensing agreement. This agreement was terminated in December 2011. PPL Energy Supply was charged $40 million of license fees in 2011. These charges were primarily included in "Other operation and maintenance" on the Statement of Income.
	Distribution of Interest in PPL Global to Parent
	In January 2011, PPL Energy Supply distributed its membership interest in PPL Global to its parent, PPL Energy Funding. See Note 9 for additional information.
	Other (All Registrants except PPL)
	See Note 1 for discussions regarding the intercompany tax sharing agreement and Note 7 for a discussion regarding capital transactions by PPL Energy Supply, PPL Electric, LKE, LG&E and KU. For PPL Energy Supply, PPL Electric and LKE, see Note 1 for discussions regarding intercompany allocations of stock-based compensation expense. For PPL Energy Supply, PPL Electric, LG&E and KU, see Note 13 for discussions regarding intercompany allocations associated with defined benefits.
Louisville Gas And Electric Co [Member]	'
Related Party Transactions [Line Items]	'
Related Party Transactions	'
	16. Related Party Transactions
	PLR Contracts/Purchase of Accounts Receivable (PPL Energy Supply and PPL Electric)
	PPL Electric holds competitive solicitations for PLR generating supply. PPL EnergyPlus has been awarded a portion of the PLR generation supply through these competitive solicitations. The sales and purchases between PPL EnergyPlus and PPL Electric are included in the Statements of Income as "Unregulated wholesale energy to affiliate" by PPL Energy Supply and as "Energy purchases from affiliate" by PPL Electric.
	Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all suppliers to post collateral once credit exposures exceed defined credit limits. PPL EnergyPlus is required to post collateral with PPL Electric: (a) when the market price of electricity to be delivered by PPL EnergyPlus exceeds the contract price for the forecasted quantity of electricity to be delivered and (b) this market price exposure exceeds a contractual credit limit. Based on the current credit rating of PPL Energy Supply, as guarantor, PPL EnergyPlus' credit limit was $20 million at December 31, 2013. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts.
	PPL Electric'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 PPL EnergyPlus.
	At December 31, 2013, PPL Energy Supply had a net credit exposure of $28 million from PPL Electric from its commitment as a PLR supplier and from the sale of its accounts receivable to PPL Electric.
	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. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation.
	Support Costs (All Registrants except PPL)
	Both PPL Services and LKS provide the respective PPL and LKE subsidiaries with administrative, management and support services. Where applicable, the costs of these services are charged to the respective subsidiaries as direct support costs. General costs that cannot be directly attributed to a specific subsidiary are allocated and charged to the respective subsidiaries as indirect support costs. PPL Services uses a three-factor methodology that includes the subsidiaries' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
	LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.
	Intercompany Borrowings
	(PPL Energy Supply)
	A PPL Energy Supply subsidiary periodically holds revolving lines of credit and demand notes from certain affiliates. No balance was outstanding at December 31, 2013 and 2012. Interest earned on these revolving facilities is included in "Interest Income from Affiliates" on the Statement of Income. Interest earned on borrowings was not significant for 2013 and 2012. For 2011, interest earned on borrowings was $8 million, which was primarily attributable to borrowings by PPL Energy Funding with an interest rate of 3.77%.
	(PPL Electric)
	A PPL Electric subsidiary periodically holds revolving demand notes from certain affiliates. At December 31, 2013, $150 million was outstanding and was reflected in “Notes receivable from affiliate” on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013, was 1.92%. Interest earned on these revolving facilities was not significant for 2013, 2012 and 2011.
	(LKE)
	LKE maintains a revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. In October 2013, the revolving line of credit was reduced by $75 million and the limit as of December 31, 2013 was $225 million. The interest rates on borrowings are equal to one-month LIBOR plus a spread. No balance was outstanding at December 31, 2013. At December 31, 2012, $25 million was outstanding and was reflected in "Notes payable with affiliates" on the Balance Sheet. The interest rate on the outstanding borrowing at December 31, 2012 was 1.71%. Interest on the revolving line of credit was not significant for 2013 or 2012.
	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. At December 31, 2013, $70 million was outstanding and was reflected in "Notes receivable from affiliates" on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013 was 2.17%. Interest income on this note was not significant for 2013 or 2012.
	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 19 for additional information on intercompany derivatives.
	(PPL Energy Supply)
	Trademark Royalties
	A PPL subsidiary owned PPL trademarks and billed certain affiliates for their use under a licensing agreement. This agreement was terminated in December 2011. PPL Energy Supply was charged $40 million of license fees in 2011. These charges were primarily included in "Other operation and maintenance" on the Statement of Income.
	Distribution of Interest in PPL Global to Parent
	In January 2011, PPL Energy Supply distributed its membership interest in PPL Global to its parent, PPL Energy Funding. See Note 9 for additional information.
	Other (All Registrants except PPL)
	See Note 1 for discussions regarding the intercompany tax sharing agreement and Note 7 for a discussion regarding capital transactions by PPL Energy Supply, PPL Electric, LKE, LG&E and KU. For PPL Energy Supply, PPL Electric and LKE, see Note 1 for discussions regarding intercompany allocations of stock-based compensation expense. For PPL Energy Supply, PPL Electric, LG&E and KU, see Note 13 for discussions regarding intercompany allocations associated with defined benefits.
Kentucky Utilities Co [Member]	'
Related Party Transactions [Line Items]	'
Related Party Transactions	'
	16. Related Party Transactions
	PLR Contracts/Purchase of Accounts Receivable (PPL Energy Supply and PPL Electric)
	PPL Electric holds competitive solicitations for PLR generating supply. PPL EnergyPlus has been awarded a portion of the PLR generation supply through these competitive solicitations. The sales and purchases between PPL EnergyPlus and PPL Electric are included in the Statements of Income as "Unregulated wholesale energy to affiliate" by PPL Energy Supply and as "Energy purchases from affiliate" by PPL Electric.
	Under the standard Default Service Supply Master Agreement for the solicitation process, PPL Electric requires all suppliers to post collateral once credit exposures exceed defined credit limits. PPL EnergyPlus is required to post collateral with PPL Electric: (a) when the market price of electricity to be delivered by PPL EnergyPlus exceeds the contract price for the forecasted quantity of electricity to be delivered and (b) this market price exposure exceeds a contractual credit limit. Based on the current credit rating of PPL Energy Supply, as guarantor, PPL EnergyPlus' credit limit was $20 million at December 31, 2013. In no instance is PPL Electric required to post collateral to suppliers under these supply contracts.
	PPL Electric'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 PPL EnergyPlus.
	At December 31, 2013, PPL Energy Supply had a net credit exposure of $28 million from PPL Electric from its commitment as a PLR supplier and from the sale of its accounts receivable to PPL Electric.
	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. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation.
	Support Costs (All Registrants except PPL)
	Both PPL Services and LKS provide the respective PPL and LKE subsidiaries with administrative, management and support services. Where applicable, the costs of these services are charged to the respective subsidiaries as direct support costs. General costs that cannot be directly attributed to a specific subsidiary are allocated and charged to the respective subsidiaries as indirect support costs. PPL Services uses a three-factor methodology that includes the subsidiaries' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
	LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.
	Intercompany Borrowings
	(PPL Energy Supply)
	A PPL Energy Supply subsidiary periodically holds revolving lines of credit and demand notes from certain affiliates. No balance was outstanding at December 31, 2013 and 2012. Interest earned on these revolving facilities is included in "Interest Income from Affiliates" on the Statement of Income. Interest earned on borrowings was not significant for 2013 and 2012. For 2011, interest earned on borrowings was $8 million, which was primarily attributable to borrowings by PPL Energy Funding with an interest rate of 3.77%.
	(PPL Electric)
	A PPL Electric subsidiary periodically holds revolving demand notes from certain affiliates. At December 31, 2013, $150 million was outstanding and was reflected in “Notes receivable from affiliate” on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013, was 1.92%. Interest earned on these revolving facilities was not significant for 2013, 2012 and 2011.
	(LKE)
	LKE maintains a revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. In October 2013, the revolving line of credit was reduced by $75 million and the limit as of December 31, 2013 was $225 million. The interest rates on borrowings are equal to one-month LIBOR plus a spread. No balance was outstanding at December 31, 2013. At December 31, 2012, $25 million was outstanding and was reflected in "Notes payable with affiliates" on the Balance Sheet. The interest rate on the outstanding borrowing at December 31, 2012 was 1.71%. Interest on the revolving line of credit was not significant for 2013 or 2012.
	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. At December 31, 2013, $70 million was outstanding and was reflected in "Notes receivable from affiliates" on the Balance Sheet. No balance was outstanding at December 31, 2012. The interest rate on the loan based on the PPL affiliate's credit rating is currently equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at December 31, 2013 was 2.17%. Interest income on this note was not significant for 2013 or 2012.
	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 19 for additional information on intercompany derivatives.
	(PPL Energy Supply)
	Trademark Royalties
	A PPL subsidiary owned PPL trademarks and billed certain affiliates for their use under a licensing agreement. This agreement was terminated in December 2011. PPL Energy Supply was charged $40 million of license fees in 2011. These charges were primarily included in "Other operation and maintenance" on the Statement of Income.
	Distribution of Interest in PPL Global to Parent
	In January 2011, PPL Energy Supply distributed its membership interest in PPL Global to its parent, PPL Energy Funding. See Note 9 for additional information.
	Other (All Registrants except PPL)
	See Note 1 for discussions regarding the intercompany tax sharing agreement and Note 7 for a discussion regarding capital transactions by PPL Energy Supply, PPL Electric, LKE, LG&E and KU. For PPL Energy Supply, PPL Electric and LKE, see Note 1 for discussions regarding intercompany allocations of stock-based compensation expense. For PPL Energy Supply, PPL Electric, LG&E and KU, see Note 13 for discussions regarding intercompany allocations associated with defined benefits.

Other_Income_Expense_net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2013
Other Income (Expense) - net [Abstract]	'
Other Income (Expense) - net	'
	17. Other Income (Expense) - net
	(All Registrants)
	The breakdown of "Other Income (Expense) - net" for the years ended December 31 was:
			PPL						PPL Energy Supply
			2013		2012		2011		2013		2012		2011
	Other Income
		Earnings on securities in NDT funds	$	23	$	22	$	24	$	23	$	22	$	24
		Interest income		3		5		7				1		1
		AFUDC - equity component		10		10		7
		Net hedge gains associated with the 2011 Bridge Facility (a)						55
		Earnings (losses) from equity method investments				-8		1
		Gain on redemption of debt (b)						22
		Miscellaneous - Domestic		18		11		10		14		5		6
		Miscellaneous - U.K.				2		1
		Total Other Income		54		42		127		37		28		31
	Other Expense
		Economic foreign currency exchange contracts (Note 19)		38		52		-10
		Charitable contributions		25		10		9		4		3		3
		WPD Midlands acquisition-related costs (Note 10)						34
		Foreign currency loss on 2011 Bridge Facility						57
		U.K. stamp duty tax (Note 10)						21
		Miscellaneous - Domestic		12		16		9		3		7		5
		Miscellaneous - U.K.		2		3		3
		Total Other Expense		77		81		123		7		10		8
	Other Income (Expense) - net		$	-23	$	-39	$	4	$	30	$	18	$	23
	(a)       Represents a gain on foreign currency contracts that hedged the repayment of the 2011 Bridge Facility borrowing.
	(b)       In July 2011, as a result of PPL Electric's redemption of 7.125% Senior Secured Bonds due 2013, PPL recorded a gain on the accelerated amortization of the fair value adjustment to the debt recorded in connection with previously settled fair value hedges.
	For PPL Electric, "Other Income (Expense) – net” for 2013, 2012 and 2011 was primarily the equity component of AFUDC. The components of "Other Income (Expense) - net" for 2013 for LKE, LG&E and KU were not significant. "Other Income (Expense) - net" for 2012 for LKE and KU were primarily losses from an equity method investment. The components of "Other Income (Expense) - net" for 2012 for LG&E were not significant. The components of "Other Income (Expense) - net" for 2011 for LKE, LG&E and KU were not significant.

Fair_Value_Measurements_and_Cr

Fair Value Measurements and Credit Concentration	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements and Credit Concentration [Abstract]	'
Fair Value Measurements and Credit Concentration	'
	18. Fair Value Measurements and Credit Concentration
	(All Registrants)
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models), and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. Transfers between levels are recognized at end-of-reporting-period values. During 2013 and 2012, 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 assets and liabilities measured at fair value were:
						December 31, 2013												December 31, 2012
						Total			Level 1			Level 2			Level 3			Total		Level 1		Level 2		Level 3
	PPL
	Assets
		Cash and cash equivalents				$	1,102		$	1,102								$	901	$	901
		Restricted cash and cash equivalents (a)					156			156									135		135
		Price risk management assets:
			Energy commodities				1,188			3		$	1,123		$	62			2,068		2	$	2,037	$	29
			Interest rate swaps				91						91						15				15
			Cross-currency swaps																14				13		1
		Total price risk management assets					1,279			3			1,214			62			2,097		2		2,065		30
		NDT funds:
			Cash and cash equivalents				14			14									11		11
			Equity securities
				U.S. large-cap			547			409			138						412		308		104
				U.S. mid/small-cap			81			33			48						60		25		35
			Debt securities
				U.S. Treasury			95			95									95		95
				U.S. government sponsored agency			6						6						9				9
				Municipality			77						77						82				82
				Investment-grade corporate			38						38						40				40
				Other			5						5						3				3
			Receivables (payables), net				1			-1			2								-2		2
		Total NDT funds					864			550			314						712		437		275
		Auction rate securities (b)					19									19			19				3		16
	Total assets					$	3,420		$	1,811		$	1,528		$	81		$	3,864	$	1,475	$	2,343	$	46
	Liabilities
		Price risk management liabilities:
			Energy commodities			$	1,070		$	4		$	1,028		$	38		$	1,566	$	2	$	1,557	$	7
			Interest rate swaps				36						36						80				80
			Foreign currency contracts				106						106						44				44
			Cross-currency swaps				32						32						4				4
		Total price risk management liabilities				$	1,244		$	4		$	1,202		$	38		$	1,694	$	2	$	1,685	$	7
	PPL Energy Supply
	Assets
		Cash and cash equivalents				$	239		$	239								$	413	$	413
		Restricted cash and cash equivalents (a)					85			85									63		63
		Price risk management assets:
			Energy commodities				1,188			3		$	1,123		$	62			2,068		2	$	2,037	$	29
		Total price risk management assets					1,188			3			1,123			62			2,068		2		2,037		29
		NDT funds:
			Cash and cash equivalents				14			14									11		11
			Equity securities
				U.S. large-cap			547			409			138						412		308		104
				U.S. mid/small-cap			81			33			48						60		25		35
			Debt securities
				U.S. Treasury			95			95									95		95
				U.S. government sponsored agency			6						6						9				9
				Municipality			77						77						82				82
				Investment-grade corporate			38						38						40				40
				Other			5						5						3				3
			Receivables (payables), net				1			-1			2								-2		2
		Total NDT funds					864			550			314						712		437		275
		Auction rate securities (b)					16									16			16				3		13
	Total assets					$	2,392		$	877		$	1,437		$	78		$	3,272	$	915	$	2,315	$	42
	Liabilities
		Price risk management liabilities:
			Energy commodities			$	1,070		$	4		$	1,028		$	38		$	1,566	$	2	$	1,557	$	7
	Total price risk management liabilities				$	1,070		$	4		$	1,028		$	38		$	1,566	$	2	$	1,557	$	7
PPL Electric
Assets
	Cash and cash equivalents				$	25		$	25								$	140	$	140
	Restricted cash and cash equivalents (c)					12			12									13		13
Total assets					$	37		$	37								$	153	$	153
LKE
Assets
	Cash and cash equivalents				$	35		$	35								$	43	$	43
	Restricted cash and cash equivalents (d)					22			22									32		32
	Price risk management assets:
		Interest rate swaps																14			$	14
	Total price risk management assets																	14				14
Total assets					$	57		$	57								$	89	$	75	$	14
Liabilities
	Price risk management liabilities:
		Interest rate swaps			$	36					$	36					$	58			$	58
	Total price risk management liabilities				$	36					$	36					$	58			$	58
LG&E
Assets
	Cash and cash equivalents				$	8		$	8								$	22	$	22
	Restricted cash and cash equivalents (d)					22			22									32		32
	Price risk management assets:
		Interest rate swaps																7			$	7
	Total price risk management assets																	7				7
Total assets					$	30		$	30								$	61	$	54	$	7
Liabilities
	Price risk management liabilities:
		Interest rate swaps			$	36					$	36					$	58			$	58
	Total price risk management liabilities				$	36					$	36					$	58			$	58
KU
Assets
	Cash and cash equivalents				$	21		$	21								$	21	$	21
	Price risk management assets:
		Interest rate swaps																7			$	7
	Total price risk management assets																	7				7
Total assets					$	21		$	21								$	28	$	21	$	7
(a)       Current portion is included in "Restricted cash and cash equivalents" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
(b)       Included in "Other investments" on the Balance Sheets.
(c)       Current portion is included in "Other current assets" and the long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
(d)       Included in "Other noncurrent assets" on the Balance Sheets.
A reconciliation of net assets and liabilities classified as Level 3 for the years ended December 31 is as follows:
						PPL
						Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
						Energy			Auction			Cross-
						Commodities,			Rate			Currency
						net			Securities			Swaps			Total
2013
Balance at beginning of period						$	22		$	16		$	1		$	39
		Total realized/unrealized gains (losses)
				Included in earnings			-5									-5
				Included in OCI (a)									1			1
		Sales					-2									-2
		Settlements					-3									-3
		Transfers into Level 3					10			3			3			16
		Transfers out of Level 3					2						-5			-3
Balance at end of period						$	24		$	19		$			$	43
2012
Balance at beginning of period						$	13		$	24		$	4		$	41
		Total realized/unrealized gains (losses)
				Included in earnings			2						-1			1
				Included in OCI (a)			1						1			2
		Sales								-5						-5
		Settlements					-13									-13
		Transfers into Level 3					8									8
		Transfers out of Level 3					11			-3			-3			5
Balance at end of period						$	22		$	16		$	1		$	39
(a)       "Energy Commodities" and "Cross-Currency Swaps" are included in "Qualifying derivatives" and "Auction Rate Securities" are included in "Available-for-sale securities" on the Statements of Comprehensive Income.
A reconciliation of net assets and liabilities classified as Level 3 for the years ended December 31 is as follows:
						PPL Energy Supply
						Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
						Energy			Auction
						Commodities,			Rate
						net			Securities			Total
2013
Balance at beginning of period						$	22		$	13		$	35
		Total realized/unrealized gains (losses)
				Included in earnings			-5						-5
		Sales					-2						-2
		Settlements					-3						-3
		Transfers into Level 3					10			3			13
		Transfers out of Level 3					2						2
Balance at end of period						$	24		$	16		$	40
2012
Balance at beginning of period						$	13		$	19		$	32
		Total realized/unrealized gains (losses)
				Included in earnings			2						2
				Included in OCI (a)			1						1
		Sales								-3			-3
		Settlements					-13						-13
		Transfers into Level 3					8						8
		Transfers out of Level 3					11			-3			8
Balance at end of period						$	22		$	13		$	35
(a)       "Energy Commodities" are included in "Qualifying derivatives" and "Auction Rate Securities" are included in "Available-for-sale securities" on the Statements of Comprehensive Income.
The significant unobservable inputs used in and quantitative information about the fair value measurement of assets and liabilities classified as Level 3 are as follows:
			December 31, 2013
			Fair Value, net				Significant		Range
			Asset		Valuation		Unobservable		(Weighted
			(Liability)		Technique		Input(s)		Average) (a)
PPL
Energy commodities
	Retail natural gas sales contracts (b)	$	36		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		10% - 100% (86%)
	Full-requirement sales contracts (c)		-12		Discounted cash flow		Proprietary model		100% (100%)
Auction rate securities (f)			19		Discounted cash flow		Modeled from SIFMA Index		10% - 80% (63%)
PPL Energy Supply
Energy commodities
	Retail natural gas sales contracts (b)	$	36		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		10% - 100% (86%)
	Full-requirement sales contracts (c)		-12		Discounted cash flow		Proprietary model		100% (100%)
Auction rate securities (f)			16		Discounted cash flow		Modeled from SIFMA Index		10% - 80% (63%)
			December 31, 2012
			Fair Value, net				Significant		Range
			Asset		Valuation		Unobservable		(Weighted
			(Liability)		Technique		Input(s)		Average) (a)
PPL
Energy commodities
	Retail natural gas sales contracts (b)	$	24		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		21% - 100% (75%)
	Power sales contracts (d)		-4		Discounted cash flow		Proprietary model used to calculate forward basis prices		24% (24%)
	FTR purchase contracts (e)		2		Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
Auction rate securities (f)			16		Discounted cash flow		Modeled from SIFMA Index		54% - 74% (64%)
Cross-currency swaps (g)			1		Discounted cash flow		Credit valuation adjustment		22% (22%)
PPL Energy Supply
Energy commodities
	Retail natural gas sales contracts (b)	$	24		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		21% - 100% (75%)
	Power sales contracts (d)		-4		Discounted cash flow		Proprietary model used to calculate forward basis prices		24% (24%)
	FTR purchase contracts (e)		2		Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
Auction rate securities (f)			13		Discounted cash flow		Modeled from SIFMA Index		57% - 74% (65%)
(a)       For energy commodities and auction rate securities, the range and weighted average represent the percentage of fair value derived from the unobservable inputs. For cross-currency swaps, the range and weighted average represent the percentage decrease in fair value due to the unobservable inputs used in the model to calculate the credit valuation adjustment.
(b)       As the forward price of natural gas increases/(decreases), the fair value of contracts (decreases)/increases.
(c)       As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases. As the volumetric assumptions for full-requirement sales contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases). As the volumetric assumptions for full-requirement sales contracts in a loss position increase/(decrease), the fair value of contracts (decreases)/increases.
(d)       As the forward price of basis increases/(decreases), the fair value of contracts (decreases)/increases.
(e)       As the forward implied spread increases/(decreases), the fair value of contracts increases/(decreases).
(f)       The model used to calculate fair value incorporates an assumption that the auctions will continue to fail. As the modeled forward rates of the SIFMA Index increase/(decrease), the fair value of the securities increases/(decreases).
(g)       The credit valuation adjustment incorporates projected probabilities of default and estimated recovery rates. As the credit valuation adjustment increases/(decreases), the fair value of the swaps (decreases)/increases.
Net gains and losses on assets and liabilities classified as Level 3 and included in earnings for the years ended December 31 were reported in the Statements of Income as follows:
																									Cross-Currency
				Energy Commodities, net																					Swaps
				Unregulated						Unregulated Retail											Energy				Interest
				Wholesale Energy						Energy								Fuel			Purchases				Expense
				2013			2012			2013				2012			2013		2012		2013		2012		2013	2012
PPL
Total gains (losses) included in earnings				$	-36		$	-19			$	25		$	26		$	3			$	3	$	-5		$	-1
Change in unrealized gains (losses) relating to
	positions still held at the reporting date				-23			-3				24			29							1		1
PPL Energy Supply
Total gains (losses) included in earnings					-36			-19				25			26			3				3		-5
Change in unrealized gains (losses) relating to
	positions still held at the reporting date				-23			-3				24			29							1		1
Price Risk Management Assets/Liabilities - Energy Commodities (PPL and PPL Energy Supply)
Energy commodity contracts are generally valued using the income approach, except for exchange-traded derivative contracts, which are valued using the market approach and are classified as Level 1. When the lowest level inputs that are significant to the fair value measurement of a contract are observable, the contract is classified as Level 2. Level 2 contracts are valued using inputs which may include quotes obtained from an exchange (where there is insufficient market liquidity to warrant inclusion in Level 1), binding and non-binding broker quotes, prices posted by ISOs or published tariff rates. Furthermore, independent quotes are obtained from the market to validate the forward price curves. Energy commodity contracts include forwards, futures, swaps, options and structured transactions and may be offset with similar positions in exchange-traded markets. To the extent possible, fair value measurements utilize various inputs that include quoted prices for similar contracts or market-corroborated inputs. In certain instances, these contracts may be valued using models, including standard option valuation models and standard industry models.
When unobservable inputs are significant to the fair value measurement, a contract is classified as Level 3. Level 3 contracts are valued using PPL proprietary models which may include significant unobservable inputs such as delivery at a location where pricing is unobservable, delivery dates that are beyond the dates for which independent quotes are available, implied volatilities, implied correlations and market implied heat rates. Forward transactions, including forward transactions classified as Level 3, are analyzed by PPL's Risk Management department, which reports to the Chief Financial Officer (CFO). Accounting personnel, who also report to the CFO, interpret the analysis quarterly to appropriately classify the forward transactions in the fair value hierarchy. Valuation techniques are evaluated periodically. Additionally, Level 2 and Level 3 fair value measurements include adjustments for credit risk based on PPL's own creditworthiness (for net liabilities) and its counterparties' creditworthiness (for net assets). PPL's credit department assesses all reasonably available market information which is used by accounting personnel to calculate the credit valuation adjustment.
In certain instances, energy commodity contracts are transferred between Level 2 and Level 3. The primary reasons for the transfers during 2013 and 2012 were changes in the availability of market information and changes in the significance of the unobservable inputs utilized in the valuation of the contract. As the delivery period of a contract becomes closer, market information may become available. When this occurs, the model's unobservable inputs are replaced with observable market information.
Price Risk Management Assets/Liabilities - Interest Rate Swaps/Foreign Currency Contracts/Cross-Currency Swaps (PPL, LKE, LG&E and KU)
To manage interest rate risk, PPL, LKE, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. To manage foreign currency exchange risk, PPL uses foreign currency contracts such as forwards, options, and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR and government security rates) and forward foreign currency exchange rates (e.g., GBP), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3. For PPL, the primary reason for the transfers during 2012 and 2013 was the change in the significance of the credit valuation adjustment. Cross-currency swaps classified as Level 3 are valued by PPL's Treasury department, which reports to the CFO. Accounting personnel, who also report to the CFO, interpret analysis quarterly to classify the contracts in the fair value hierarchy. Valuation techniques are evaluated periodically.
(PPL and PPL Energy Supply)
NDT Funds
The market approach is used to measure the fair value of equity securities held in the NDT funds.
       The fair value measurements of equity securities classified as Level 1 are based on quoted prices in active markets.
       The fair value measurements of investments in commingled equity funds are classified as Level 2. These fair value measurements are based on firm quotes of net asset values per share, which are not obtained from a quoted price in an active market.
The fair value of debt securities is generally measured using a market approach, including the use of pricing models, which incorporate observable inputs. Common inputs include benchmark yields, reported trades, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as monthly payment data, future predicted cash flows, collateral performance and new issue data.
Auction Rate Securities
Auction rate securities include Federal Family Education Loan Program guaranteed student loan revenue bonds, as well as various municipal bond issues. The probability of realizing losses on these securities is not significant.
The fair value of auction rate securities is estimated using an income approach that includes readily observable inputs, such as principal payments and discount curves for bonds with credit ratings and maturities similar to the securities, and unobservable inputs, such as future interest rates that are estimated based on the SIFMA Index, creditworthiness, and liquidity assumptions driven by the impact of auction failures. When the present value of future interest payments is significant to the overall valuation, the auction rate securities are classified as Level 3. The primary reason for the transfers in and out of Level 3 in 2013 and 2012 was the change in discount rates and SIFMA Index.
Auction rate securities are valued by PPL's Treasury department, which reports to the CFO. Accounting personnel, who also report to the CFO, interpret the analysis quarterly to classify the contracts in the fair value hierarchy. Valuation techniques are evaluated periodically.
Nonrecurring Fair Value Measurements (All Registrants except PPL Electric and LG&E)
The following nonrecurring fair value measurements occurred during the reporting periods, resulting in asset impairments.
				Carrying			Fair Value Measurements Using
				Amount (a)			Level 2			Level 3			Loss (b)
PPL and PPL Energy Supply
	Corette plant and emission allowances:
		2013		$	65								$	65
	RECs (c):
		2011			6		$	1						5
PPL, LKE and KU
	Equity investment in EEI:
		2012			25									25
(a)       Represents carrying value before fair value measurement.
(b)       The loss on the Corette plant and emission allowances was recorded in the Supply segment and included in "Other operation and maintenance" on the Statement of Income. The loss on the EEI investment was recorded in the Kentucky Regulated segment and included in "Other-Than-Temporary Impairments" on the Statement of Income. Losses on RECs were recorded in the Supply segment and included in "Other operation and maintenance" on the Statements of Income.
(c)       Current and long-term RECs are included in "Other current assets" and "Other intangibles" in their respective areas on the Balance Sheets.
The significant unobservable inputs used in and the quantitative information about the nonrecurring fair value measurement of assets and liabilities classified as Level 3 are as follows:
			Fair Value, net				Significant		Range
			Asset		Valuation		Unobservable		(Weighted
			(Liability)		Technique		Input(s)		Average)
PPL and PPL Energy Supply
Corette plant and emission allowances:
	31-Dec-13		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
PPL, LKE and KU
Equity investment in EEI:
	31-Dec-12		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
(PPL and PPL Energy Supply)
Corette Plant and Emission Allowances
During the fourth quarter 2013, PPL Montana recorded an impairment loss on the Corette plant and related emission allowances. In connection with the completion of its annual business planning process that included revised long-term power and gas price assumptions and other factors, PPL Energy Supply has now determined that it is less likely that the Corette plant will restart after operations are suspended no later than April 2015. PPL Energy Supply performed an internal analysis using an income approach based on discounted cash flows to assess the fair value of the Corette asset group. Assumptions used in the fair value assessment were forward energy prices, expectations for demand for energy in Corette's market, and expected operation and maintenance and capital expenditures that were consistent with assumptions used in the business planning process. Through this analysis, PPL Energy Supply determined the fair value of the asset group to be negligible.
The assets were valued by the PPL Energy Supply Financial Department, which reports to the President of PPL Energy Supply. Accounting personnel, who report to the Chief Financial Officer, interpreted the analysis to appropriately classify the assets in the fair value hierarchy.
RECs
Due to declines in forecasted full-requirement obligations in certain markets as well as declines in market prices, PPL Energy Supply assessed the recoverability of certain RECs not expected to be used. Observable market prices (Level 2) were used to value the RECs.
Equity Investment in EEI (PPL, LKE and KU)
During the fourth quarter 2012, KU recorded an other-than-temporary decline in the value of its equity investment in EEI. KU performed an internal analysis using an income approach based on discounted cash flows to assess the current fair value of its investment based on several factors. KU considered the following factors: long-dated forward power and fuel price curves, the cost of compliance with environmental standards, and the majority owner and operator's announcement in the fourth quarter 2012 to exit from the merchant generation business. Assumptions used in the fair value assessment were forward energy price curves, expectations for capacity (demand) for energy in EEI's market, and expected capital expenditures used in the calculation that were comparable to assumptions used by KU for internal budgeting and forecasting purposes. Through this analysis, KU determined the fair value to be zero.
Financial Instruments Not Recorded at Fair Value (All Registrants)
The carrying amounts of contract adjustment payments related to the Purchase Contract component of the Equity Units and long-term debt on the Balance Sheets and their estimated fair values are set forth below. The fair values of these instruments 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. These instruments are classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.
			December 31, 2013						December 31, 2012
			Carrying						Carrying
			Amount			Fair Value			Amount			Fair Value
PPL
	Contract adjustment payments (a)		$	21		$	22		$	105		$	106
	Long-term debt			20,907			22,177			19,476			21,671
PPL Energy Supply
	Long-term debt			2,525			2,658			3,272			3,556
PPL Electric
	Long-term debt			2,315			2,483			1,967			2,333
LKE
	Long-term debt			4,565			4,672			4,075			4,423
LG&E
	Long-term debt			1,353			1,372			1,112			1,178
KU
	Long-term debt			2,091			2,155			1,842			2,056
(a)       Included in "Other current liabilities" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
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.
Credit Concentration Associated with Financial Instruments
(All Registrants)
Contracts are entered into with many entities for the purchase and sale of energy. When NPNS is elected, the fair value of these contracts is not reflected in the financial statements. However, the fair value of these contracts is considered when committing to new business from a credit perspective. See Note 19 for information on credit policies used to manage credit risk, including master netting arrangements and collateral requirements.
(PPL)
At December 31, 2013, PPL had credit exposure of $1.0 billion from energy trading partners, excluding the effects of netting arrangements, reserves and collateral. As a result of netting arrangements, reserves and collateral, PPL's credit exposure was reduced to $539 million. The top ten counterparties including their affiliates accounted for $281 million, or 52%, of this exposure. Nine of these counterparties had an investment grade credit rating from S&P or Moody's and accounted for 95% of the top ten exposures. The remaining counterparty has not been rated by S&P or Moody's, but is current on its obligations.
(PPL Energy Supply)
At December 31, 2013, PPL Energy Supply had credit exposure of $1.0 billion from energy trading partners, excluding exposure from related parties and the effects of netting arrangements, reserves and collateral. As a result of netting arrangements, reserves and collateral, this credit exposure was reduced to $536 million. The top ten counterparties including their affiliates accounted for $281 million, or 52%, of this exposure. Nine of these counterparties had an investment grade credit rating from S&P or Moody's and accounted for 95% of the top ten exposures. The remaining counterparty has not been rated by S&P or Moody's, but is current on its obligations. See Note 16 for information regarding the related party credit exposure.
(PPL Electric)
PPL Electric is exposed to credit risk under energy supply contracts (including its supply contracts with PPL EnergyPlus); however, its PUC-approved recovery mechanism is anticipated to substantially eliminate this exposure.
(LKE, LG&E and KU)
At December 31, 2013, LKE's, LG&E's and KU's credit exposure was not significant.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities [Abstract]	'
Derivative Instruments and Hedging Activities	'
	19. 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 (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The RMC, comprised of senior management and chaired by 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 and market prices, verification of risk and transaction limits, VaR analyses, portfolio stress tests, gross margin at risk analyses, sensitivity analyses and daily portfolio reporting, including open positions, determinations of fair value and other risk management metrics.
	Market Risk
	Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices, volumes of full-requirement sales contracts, basis exposure, interest rates and/or 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 table below summarizes the market risks that affect PPL and its Subsidiary Registrants.
							PPL			PPL
				PPL			Energy Supply			Electric			LKE			LG&E			KU
	Commodity price risk (including basis and
		volumetric risk)		X			X			M			M			M			M
	Interest rate risk:
		Debt issuances		X			X			M			M			M			M
		Defined benefit plans		X			X			M			M			M			M
		NDT securities		X			X
	Equity securities price risk:
		Defined benefit plans		X			X			M			M			M			M
		NDT securities		X			X
		Future stock transactions		X
	Foreign currency risk - WPD investment and
		earnings		X
	X       =PL and PPL Energy Supply actively mitigate market risks through their risk management programs described above.
	M       =/font>The regulatory environments for PPL's regulated entities, by definition, significantly mitigate market risk.
	Commodity price risk
	       PPL is exposed to commodity price risk through its domestic subsidiaries as described below. Volumetric risk is significantly mitigated at WPD as a result of the method of regulation in the U.K.
	       PPL Energy Supply is exposed to commodity price risk for energy and energy-related products associated with the sale of electricity from its generating assets and other electricity and gas marketing activities and the purchase of fuel and fuel-related commodities for generating assets, as well as for proprietary trading activities.
	       PPL Electric is exposed to commodity price risk from its obligation as PLR; however, its PUC-approved cost recovery mechanism substantially eliminates its exposure to this risk. PPL Electric also mitigates its exposure to 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 obligation to the energy suppliers.
	       LG&E's and KU's rates include certain mechanisms for fuel, gas supply and environmental expenses. These mechanisms generally provide for timely recovery of market price and volumetric fluctuations associated with these expenses.
	Interest rate risk
	       PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. WPD holds 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 and LG&E and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates in connection with future debt issuances.
	       PPL and its subsidiaries are exposed to interest rate risk associated with debt securities held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated domestic utilities and for certain plans at WPD due to the recovery mechanisms in place. Additionally, PPL Energy Supply is exposed to interest rate risk associated with debt securities held by the NDT.
	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. Additionally, PPL Energy Supply is exposed to equity securities price risk in the NDT funds.
	       PPL is exposed to equity securities price risk from future stock sales and/or purchases.
	Foreign currency risk
	       PPL is exposed to foreign currency exchange risk primarily associated with its investments and earnings in U.K. affiliates.
	Credit Risk
	Credit risk is the potential loss that may be incurred due to a counterparty's non-performance.
	PPL is exposed to credit risk from "in-the-money" interest rate and foreign currency derivatives with financial institutions, as well as additional credit risk through certain of its subsidiaries, as discussed below.
	PPL Energy Supply is exposed to credit risk from "in-the-money" commodity derivatives with its energy trading partners, which include other energy companies, fuel suppliers, financial institutions, other wholesale customers and retail customers.
	LKE and LG&E are exposed to credit risk from interest rate derivatives with third-party financial institutions.
	The majority of PPL and PPL Energy Supply's credit risk stems from commodity derivatives for multi-year contracts for energy sales and purchases. If PPL Energy Supply's counterparties fail to perform their obligations under such contracts and PPL Energy Supply could not replace the sales or purchases at the same or better prices as those under the defaulted contracts, PPL Energy Supply would incur financial losses. Those losses would be recognized immediately or through lower revenues or higher costs in future years, depending on the accounting treatment for the defaulted contracts. 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 market. In general, incremental costs incurred by these entities would be recoverable from customers in future rates, thus mitigating the financial risk for these entities.
	PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit. See Note 18 for credit concentration associated with energy trading partners.
	Master Netting Arrangements
	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
	PPL's and PPL Energy Supply's obligation to return counterparty cash collateral under master netting arrangements was $9 million and $112 million at December 31, 2013 and 2012.
	PPL Electric, LKE and LG&E had no obligation to return cash collateral under master netting arrangements at December 31, 2013 and 2012.
	PPL, LKE and LG&E had posted cash collateral under master netting arrangements of $22 million and $32 million at December 31, 2013 and 2012.
	PPL Energy Supply, PPL Electric and KU had not posted any cash collateral under master netting arrangements at December 31, 2013 and 2012.
	See "Offsetting Derivative Investments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements.
	(PPL and PPL Energy Supply)
	Commodity Price Risk (Non-trading)
	Commodity price risk, including basis and volumetric risk, is among PPL's and PPL Energy Supply's most significant risks due to the level of investment that PPL and PPL Energy Supply maintain in their competitive generation assets, as well as the extent of their marketing activities. Several factors influence price levels and volatilities. These factors include, but are not limited to, seasonal changes in demand, weather conditions, available generating assets within regions, transportation/transmission availability and reliability within and between regions, market liquidity, and the nature and extent of current and potential federal and state regulations.
	PPL Energy Supply maximizes the value of its unregulated wholesale and unregulated retail energy portfolios through the use of non-trading strategies that include sales of competitive baseload generation, optimization of competitive intermediate and peaking generation and marketing activities.
	PPL Energy Supply has a formal hedging program to economically hedge the forecasted purchase and sale of electricity and related fuels for its competitive baseload generation fleet, which includes 7,369 MW (summer rating) of nuclear, coal and hydroelectric generating capacity. PPL Energy Supply attempts to optimize the overall value of its competitive intermediate and peaking fleet, which includes 3,309 MW (summer rating) of natural gas and oil-fired generation. PPL Energy Supply's marketing portfolio is comprised of full-requirement sales contracts and related supply contracts, retail natural gas and electricity sales contracts and other marketing activities. The strategies that PPL Energy Supply uses to hedge its full-requirement sales contracts include purchasing energy (at a liquid trading hub or directly at the load delivery zone), capacity and RECs in the market and/or supplying the energy, capacity and RECs from its generation assets.
	PPL and PPL Energy Supply enter into financial and physical derivative contracts, including forwards, futures, swaps and options, to hedge the price risk associated with electricity, natural gas, oil and other commodities. Certain contracts are non-derivatives or NPNS is elected and therefore they are not reflected in the financial statements until delivery. PPL and PPL Energy Supply segregate their non-trading activities into two categories: cash flow hedges and economic activity as discussed below.
	Cash Flow Hedges
	Certain derivative contracts have qualified for hedge accounting so that the effective portion of a derivative's gain or loss is deferred in AOCI and reclassified into earnings when the forecasted transaction occurs. Certain cash flow hedge positions were dedesignated during 2013 and 2012 and the unamortized portion remained in AOCI because the original forecasted transaction is still expected to occur. There were no active cash flow hedges at December 31, 2013. At December 31, 2013, the accumulated net unrecognized after-tax gains (losses) that are expected to be reclassified into earnings during the next 12 months were $25 million for PPL and PPL Energy Supply. Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time periods and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedge transaction is probable of not occurring. For 2013, there were no reclassifications, while in 2012 and 2011, such reclassifications were insignificant.
	For 2013 and 2012, hedge ineffectiveness associated with energy derivatives was insignificant. For 2011, hedge ineffectiveness associated with energy derivatives was an after-tax gain (loss) of $(22) million.
	Economic Activity
	Many derivative contracts economically hedge the commodity price risk associated with electricity, natural gas, oil and other commodities but do not receive hedge accounting treatment because they were not eligible for hedge accounting or because hedge accounting was not elected. These derivatives hedge a portion of the economic value of PPL Energy Supply's competitive generation assets and unregulated full-requirement and retail contracts, which are subject to changes in fair value due to market price volatility and volume expectations. Additionally, economic activity would also include the ineffective portion of qualifying cash flow hedges (see "Cash Flow Hedges" above). The derivative contracts in this category that existed at December 31, 2013 range in maturity through 2019.
	Examples of economic activity may include hedges on sales of baseload generation, certain purchase contracts used to supply full-requirement sales contracts, FTRs or basis swaps used to hedge basis risk associated with the sale of competitive generation or supplying full-requirement sales contracts, Spark Spread hedging contracts, retail electric and natural gas activities, and fuel oil swaps used to hedge price escalation clauses in coal transportation and other fuel-related contracts. PPL Energy Supply also uses options, which include the sale of call options and the purchase of put options tied to a particular generating unit. Since the physical generating capacity is owned, price exposure is generally capped at the price at which the generating unit would be dispatched and therefore does not expose PPL Energy Supply to uncovered market price risk.
	The net fair value of economic positions at December 31, 2013 and December 31, 2012 was a net asset (liability) of $107 million and $346 million for PPL and PPL Energy Supply. The unrealized gains (losses) for economic activity were as follows.
			2013			2012			2011
Operating Revenues
	Unregulated wholesale energy		$	-721		$	-311		$	1,407
	Unregulated retail energy			12			-17			31
Operating Expenses
	Fuel			-4			-14			6
	Energy purchases			586			442			-1,123
Commodity Price Risk (Trading)
PPL Energy Supply has a proprietary trading strategy which is utilized to take advantage of market opportunities. As a result, PPL Energy Supply may at times create a net open position in its portfolio that could result in losses if prices do not move in the manner or direction anticipated. Net energy trading margins, which are included in "Unregulated wholesale energy" on the Statements of Income, were insignificant for 2013, 2012 and 2011.
Commodity Volumes
At December 31, 2013, the net volumes of derivative (sales)/purchase contracts used in support of the various strategies discussed above were as follows.
				Volumes (a)
Commodity		Unit of Measure		2014		2015		2016		Thereafter
Power		MWh		-33,278,963		-14,421,817		4,348,927		18,931,370
Capacity		MW-Month		-19,575		-3,929		501		9
Gas		MMBtu		25,869,617		-33,082,289		19,082,945		-9,202,403
Coal		Tons		495,900
FTRs		MW-Month		9,581		1,705
Oil		Barrels		150,000		380,869		274,137		101,261
(a)       Volumes for option contracts factor in the probability of an option being exercised and may be less than the notional amount of the option.
Interest Rate Risk
(PPL, LKE, LG&E and KU)
PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. Various financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolio, adjust the duration of the debt portfolio and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates.
Cash Flow Hedges
(PPL)
Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. At December 31, 2013, outstanding interest rate swap contracts range in maturity through 2044 for PPL's domestic interest rate swaps. These swaps had an aggregate notional value of $1.3 billion at December 31, 2013.
At December 31, 2013, PPL held a notional position in cross-currency interest rate swaps totaling $1.3 billion that range in maturity through 2028 to hedge the interest payments and principal of WPD's U.S. dollar-denominated senior notes.
For 2013 and 2012, hedge ineffectiveness associated with interest rate derivatives was insignificant. For 2011, hedge ineffectiveness associated with these derivatives resulted in a net after-tax gain (loss) of $(9) million, which included a gain (loss) of $(4) million attributable to certain interest rate swaps that failed hedge effectiveness testing during the second quarter of 2011.
Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is probable of not occurring. PPL had no such reclassifications for 2013, 2012 and 2011.
At December 31, 2013, 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 $(10) million. Amounts are reclassified as the hedged interest payments are made.
(LKE, LG&E and KU)
In November 2012 and April 2013, LG&E and KU entered into forward-starting interest rate swaps with PPL that hedged the interest payments on new debt that was expected to be issued in 2013. In September 2013, these hedges were terminated and LG&E and KU entered into new forward-starting interest rate swaps with PPL, effectively extending the start date of the prior hedges from September 2013 to December 2013. All of these swaps had terms identical to forward-starting swaps entered into by PPL with third parties. New debt totaling $500 million was issued in November 2013 (LG&E and KU each issued $250 million) and the hedges issued in September were terminated in November 2013. Net cash settlements of $86 million (LG&E and KU each received $43 million) were received on the swaps that were terminated in September and November, which are included in "Cash Flows from Operating Activities" on the Statement of Cash Flows. Realized gains and losses on these swaps are probable of recovery through regulated rates; as such, the net settlements were reclassified from AOCI to regulatory liabilities and are being recognized in "Interest Expense" on the Statements of Income over the life of the newly issued debt. For 2013, there was no hedge ineffectiveness recorded for the interest rate derivatives.
Fair Value Hedges
(PPL)
PPL is exposed to changes in the fair value of its debt portfolio. To manage this risk, financial contracts may be entered into to hedge fluctuations in the fair value of existing debt issuances due to changes in benchmark interest rates. In July 2012, contracts held by PPL that ranged in maturity through 2047 and had a notional value of $99 million were canceled without penalties by the counterparties. PPL did not hold any such contracts at December 31, 2013 or 2012. PPL did not recognize gains or losses resulting from the ineffective portion of fair value hedges or from a portion of the hedging instrument being excluded from the assessment of hedge effectiveness or from hedges of debt issuances that no longer qualified as fair value hedges for 2013, 2012 and 2011.
In 2011, PPL Electric redeemed $400 million of 7.125% Senior Secured Bonds due 2013. As a result of this redemption, PPL recorded a gain (loss) of $22 million, or $14 million after tax, for 2011 in "Other Income (Expense) - net" on the Statement of Income as a result of accelerated amortization of the fair value adjustments to the debt in connection with previously settled fair value hedges.
Economic Activity (PPL, LKE and LG&E)
LG&E enters into interest rate swap contracts that economically hedge interest payments on variable rate debt. Because realized gains and losses from the swaps, including 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. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income when the hedged transaction occurs. At December 31, 2013, 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 instruments to protect against foreign currency translation risk of expected 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 contracts outstanding at December 31, 2013 had a notional amount of £301 million (approximately $477 million based on contracted rates). The settlement dates of these contracts range from May 2014 through December 2015.
Additionally, a PPL Global subsidiary that has a U.S. dollar functional currency entered into GBP intercompany loans payable with PPL WEM subsidiaries that have GBP functional currency. The loans qualify as a net investment hedge for the PPL Global subsidiary. As such, the foreign currency gains and losses on the intercompany loans for the PPL Global subsidiary are recorded to the foreign currency translation adjustment component of OCI. At December 31, 2013, the outstanding balances of the intercompany loans were £42 million (approximately $69 million based on spot rates). For 2013 and 2012, PPL recognized insignificant amounts of net investment hedge after-tax gains (losses) on the intercompany loans in the foreign currency translation adjustment component of OCI.
At December 31, 2013 and 2012, PPL had an insignificant amount 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 anticipated earnings. At December 31, 2013, the total exposure hedged by PPL was approximately £1.4 billion (approximately $2.3 billion based on contracted rates). These contracts had termination dates ranging from January 2014 through December 2015.
In anticipation of the repayment of a portion of the GBP-denominated borrowings under the 2011 Bridge Facility with U.S. dollar proceeds received from PPL's issuance of common stock and 2011 Equity Units and PPL WEM's issuance of U.S. dollar-denominated senior notes, PPL entered into forward contracts to purchase GBP in order to economically hedge the foreign currency exchange rate risk related to the repayment. When these trades were settled in April 2011, PPL recorded $55 million of pre-tax, net gains (losses) in "Other Income (Expense) - net" on the Statement of Income.
Accounting and Reporting
(All Registrants)
All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNS is elected. NPNS contracts for PPL and PPL Energy Supply include certain full-requirement sales contracts, other physical purchase and sales contracts and certain retail energy and physical capacity contracts, and for PPL Electric include certain full-requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized currently in earnings unless specific hedge accounting criteria are met and designated as such, except for the change in fair value of LG&E's and KU's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at December 31, 2013 and 2012.
See Note 1 for additional information on accounting policies related to derivative instruments.
(PPL)
The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets.
							December 31, 2013												December 31, 2012
							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)				$	82								$	4		$	14		$	22					$	5
			Cross-currency swaps							$	4												3
			Foreign currency
				contracts							16						55						2						23
			Commodity contracts										$	860			750			59					$	1,452			1,010
					Total current			82			20			860			809			73			27			1,452			1,038
Noncurrent:
	Price Risk Management
		Assets/Liabilities (a):
			Interest rate swaps (b)					9									32			1									53
			Cross-currency swaps								28									14			1
			Foreign currency
				contracts							4						31												19
			Commodity contracts											328			320			27						530			556
					Total noncurrent			9			32			328			383			42			1			530			628
Total derivatives							$	91		$	52		$	1,188		$	1,192		$	115		$	28		$	1,982		$	1,666
(a)       Represents the location on the Balance Sheets
(b)       Excludes accrued interest, if applicable.
The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities.
	Derivatives in		Hedged Items in		Location of Gain
	Fair Value Hedging		Fair Value Hedging		(Loss) Recognized		Gain (Loss) Recognized			Gain (Loss) Recognized
	Relationships		Relationships		in Income		in Income on Derivative			in Income on Related Item
2012
	Interest rate swaps		Fixed rate debt		Interest Expense					$	3
2011
	Interest rate swaps		Fixed rate debt		Interest Expense		$	2			25
					Other Income (Expense) - net						22
													Gain (Loss) Recognized
													in Income on Derivative
					Derivative Gain					Gain (Loss) Reclassified			(Ineffective Portion and
			Derivative		(Loss) Recognized in			Location of Gain (Loss)		from AOCI into Income			Amount Excluded from
			Relationships		OCI (Effective Portion)			Recognized in Income		(Effective Portion)			Effectiveness Testing)
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						Unregulated wholesale energy			263		$	1
								Energy purchases			-58
								Depreciation			2
								Other			3
	Total				$	86				$	163		$	1
	Net Investment Hedges:
		Foreign currency contracts			$	-14
2012
	Cash Flow Hedges:
		Interest rate swaps			$	-28		Other income (Expense) - net		$	1
								Interest Expense			-18
		Cross-currency swaps				-15		Other Income (Expense) - net			-23
								Interest Expense			-2
		Commodity contracts				114		Unregulated wholesale energy			891		$	-1
								Energy purchases			-139			-2
								Depreciation			2
	Total				$	71				$	712		$	-3
	Net Investment Hedges:
		Foreign currency contracts			$	-7
2011
	Cash Flow Hedges:
		Interest rate swaps			$	-55		Interest Expense		$	-13		$	-13
		Cross-currency swaps				-35		Other Income (Expense) - net			29
								Interest Expense			5
		Commodity contracts				431		Unregulated wholesale energy			835			-39
								Fuel			1
								Energy purchases			-243			1
								Depreciation			2
	Total				$	341				$	616		$	-51
	Net Investment Hedges:
		Foreign currency contracts			$	6
Derivatives Not Designated as		Location of Gain (Loss) Recognized in
Hedging Instruments		Income on Derivatives			2013			2012			2011
Foreign currency contracts		Other Income (Expense) - net		$	-38		$	-52		$	65
Interest rate swaps		Interest Expense			-8			-8			-8
Commodity contracts		Utility									-1
		Unregulated wholesale energy			-85			1,199			1,600
		Unregulated retail energy			25			30			39
		Fuel			2						-1
		Energy purchases			130			-965			-1,493
		Total		$	26		$	204		$	201
Derivatives Not Designated as		Location of Gain (Loss) Recognized as
Hedging Instruments		Regulatory Liabilities/Assets			2013			2012			2011
Interest rate swaps		Regulatory assets - noncurrent		$	22		$	1		$	-26
Derivatives Designated as		Location of Gain (Loss) Recognized as
Cash Flow Hedges		Regulatory Liabilities/Assets			2013			2012			2011
Interest rate swaps		Regulatory liabilities - noncurrent		$	72		$	14
(PPL Energy Supply)
The following tables present the fair value and location of derivative instruments recorded on the Balance Sheets.
							December 31, 2013												December 31, 2012
							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):
			Commodity contracts										$	860		$	750		$	59					$	1,452		$	1,010
					Total current									860			750			59						1,452			1,010
Noncurrent:
	Price Risk Management
		Assets/Liabilities (a):
			Commodity contracts											328			320			27						530			556
					Total noncurrent									328			320			27						530			556
Total derivatives													$	1,188		$	1,070		$	86					$	1,982		$	1,566
(a)       Represents the location on the Balance Sheet.
The following tables present the pre-tax effect of derivative instruments recognized in income or OCI. There were no gains (losses) on interest rate swaps for 2013 or 2012.
	Derivatives in		Hedged Items in		Location of Gain
	Fair Value Hedging		Fair Value Hedging		(Loss) Recognized		Gain (Loss) Recognized			Gain (Loss) Recognized
	Relationships		Relationships		in Income		in Income on Derivative			in Income on Related Item
2011
	Interest rate swaps		Fixed rate debt		Interest Expense					$	2
													Gain (Loss) Recognized
													in Income on Derivative
					Derivative Gain					Gain (Loss) Reclassified			(Ineffective Portion and
			Derivative		(Loss) Recognized in			Location of Gain (Loss)		from AOCI into Income			Amount Excluded from
			Relationships		OCI (Effective Portion)			Recognized in Income		(Effective Portion)			Effectiveness Testing)
2013
	Cash Flow Hedges:
		Commodity contracts						Unregulated wholesale energy		$	263		$	1
								Depreciation			2
								Energy purchases			-58
	Total									$	207		$	1
2012
	Cash Flow Hedges:
		Commodity contracts			$	114		Unregulated wholesale energy		$	891		$	-1
								Depreciation			2
								Energy purchases			-139			-2
	Total				$	114				$	754		$	-3
2011
	Cash Flow Hedges:
		Commodity contracts			$	431		Unregulated wholesale energy		$	835		$	-39
								Fuel			1
								Energy purchases			-243			1
								Depreciation			2
	Total				$	431				$	595		$	-38
Derivatives Not Designated as		Location of Gain (Loss) Recognized in
Hedging Instruments		Income on Derivatives			2013			2012			2011
Commodity contracts		Unregulated wholesale energy		$	-85		$	1,199		$	1,600
		Unregulated retail energy			25			30			39
		Fuel			2						-1
		Energy purchases			130			-965			-1,493
		Total		$	72		$	264		$	145
(LKE)
The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges.
							December 31, 2013							December 31, 2012
							Assets			Liabilities				Assets			Liabilities
Current:
	Price Risk Management
		Assets/Liabilities (a):
			Interest rate swaps											$	14
(a)       Represents the location on the Balance Sheet.
The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory liabilities.
Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
Interest rate swaps		Regulatory liabilities - noncurrent		$	72		$	14
(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, 2013							December 31, 2012
							Assets			Liabilities				Assets			Liabilities
Current:
	Price Risk Management
		Assets/Liabilities (a):
			Interest rate swaps											$	7
(a)       Represents the location on the balance sheet.
The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory liabilities.
Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
Interest rate swaps		Regulatory liabilities - noncurrent		$	36		$	7
(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, 2013							December 31, 2012
							Assets			Liabilities				Assets			Liabilities
Current:
	Price Risk Management
		Assets/Liabilities (a):
			Interest rate swaps											$	7
(a)       Represents the location on the Balance Sheets.
The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory liabilities.
Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
Interest rate swaps		Regulatory liabilities - noncurrent		$	36		$	7
(LKE and LG&E)
The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.
							December 31, 2013						December 31, 2012
							Assets			Liabilities				Assets			Liabilities
Current:
	Price Risk Management
		Assets/Liabilities (a):
			Interest rate swaps							$	4						$	5
					Total current						4							5
Noncurrent:
	Price Risk Management
		Assets/Liabilities (a):
			Interest rate swaps								32							53
					Total noncurrent						32							53
Total derivatives										$	36						$	58
(a)       Represents the location on the Balance Sheets.
The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets.
Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
Interest rate swaps		Interest Expense		$	-8		$	-8		$	-8
Commodity contracts		Operating Revenues									-1
		Total		$	-8		$	-8		$	-9
Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
Interest rate swaps		Regulatory assets - noncurrent		$	22		$	1		$	-26
(All Registrants except PPL Electric)
Offsetting Derivative Instruments
PPL, PPL Energy Supply, LKE, LG&E and KU or certain of their subsidiaries have master netting arrangements or similar agreements in place including derivative clearing agreements with futures commission merchants (FCMs) to permit the trading of cleared derivative products on one or more futures exchanges. The clearing arrangements permit an FCM to use and apply any property in its possession as a set off to pay amounts or discharge obligations owed by a customer upon default of the customer and typically do not place any restrictions on the FCM's use of collateral posted by the customer. PPL, PPL Energy Supply, LKE, LG&E and KU and their subsidiaries also enter into agreements pursuant to which they trade 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 setoff 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, PPL Energy Supply, LKE, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
					Assets												Liabilities
								Eligible for Offset												Eligible for Offset
											Cash												Cash
								Derivative			Collateral									Derivative			Collateral
					Gross			Instruments			Received			Net			Gross			Instruments			Pledged			Net
December 31, 2013
PPL
	Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
	Treasury Derivatives					91			61						30			174			61			23			90
Total					$	1,279		$	973		$	7		$	299		$	1,244		$	973		$	24		$	247
PPL Energy Supply
	Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
LKE
	Treasury Derivatives																$	36					$	20		$	16
LG&E
	Treasury Derivatives																$	36					$	20		$	16
December 31, 2012
PPL
	Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
	Treasury Derivatives					29			19						10			128			19			30			79
Total					$	2,097		$	1,432		$	111		$	554		$	1,694		$	1,432		$	39		$	223
PPL Energy Supply
	Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
LKE
	Treasury Derivatives				$	14								$	14		$	58					$	30		$	28
LG&E
	Treasury Derivatives				$	7								$	7		$	58					$	30		$	28
KU
	Treasury Derivatives				$	7								$	7
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, PPL Energy Supply, LKE, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in the credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade (i.e., below BBB- for S&P or Fitch, or Baa3 for Moody's), and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions.
Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's obligation under the contract. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.
At December 31, 2013, the effect of a decrease in credit ratings below investment grade on derivative contracts that contain credit risk-related contingent features and were in a net liability position is summarized as follows:
							PPL
				PPL			Energy Supply			LKE			LG&E
Aggregate fair value of derivative instruments in a net liability
	position with credit risk-related contingent features			$	245		$	157		$	26		$	26
Aggregate fair value of collateral posted on these derivative instruments					41			19			22			22
Aggregate fair value of additional collateral requirements in the event of
	a credit downgrade below investment grade (a)				214			147			6			6
(a)       Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Goodwill_and_Other_Intangible_

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2013
Goodwill and Other Intangible Assets [Abstract]	'
Goodwill and Other Intangible Assets	'
	20. Goodwill and Other Intangible Assets
	Goodwill
	(PPL)
	The changes in the carrying amount of goodwill by segment were:
						U.K. Regulated						Kentucky Regulated					Supply				Total
						2013			2012			2013			2012		2013		2012		2013		2012
	PPL
	Balance at beginning of period (a)					$	3,076		$	3,032		$	662		$	662	$	420	$	420	$	4,158	$	4,114
		Changes during the period (b)					67			44												67		44
	Balance at end of period (a)					$	3,143		$	3,076		$	662		$	662	$	420	$	420	$	4,225	$	4,158
	(a)       There were no accumulated impairment losses related to goodwill.
	(b)       Primarily the effect of foreign currency exchange rates.
	Other Intangible Assets
	(PPL)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Contracts (a)			$	408		$	202		$	408		$	150
		Land and transmission rights				331			117			284			113
		Emission allowances/RECs (b)				16						17
		Licenses and other (c)				305			45			287			39
	Total subject to amortization					1,060			364			996			302
	Not subject to amortization due to indefinite life:
		Land and transmission rights				16						18
		Easements (d)				239						220
	Total not subject to amortization due to indefinite life					255						238
	Total				$	1,315		$	364		$	1,234		$	302
	(a)       Gross carrying amount includes the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition of LKE 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. 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)       "Other" includes costs for the development of licenses, the most significant of which is the COLA. Amortization of these costs begins when the related asset is placed in service. See Note 8 for additional information on the COLA.
	(d)       Gross carrying amount includes $88 million, which represents the fair value at the acquisition date of easements recognized as a result of the 2011 acquisition of WPD Midlands. See Note 10 for additional information.
	Current intangible assets are included in "Other current assets" and long-term intangible assets are included in "Other intangibles" on the Balance Sheets.
	Amortization expense for the years ended December 31, excluding consumption of emission allowances/RECs of $23 million, $12 million, and $16 million in 2013, 2012 and 2011, was as follows:
				2013			2012			2011
	Intangible assets with no regulatory offset		$	10		$	14		$	25
	Intangible assets with regulatory offset			51			47			87
	Total		$	61		$	61		$	112
	Amortization expense for each of the next five years, excluding insignificant amounts for consumption of emission allowances/RECs, is estimated to be:
				2014			2015			2016			2017			2018
	Intangible assets with no regulatory offset		$	10		$	10		$	8		$	8		$	8
	Intangible assets with regulatory offset			48			50			27			9			9
	Total		$	58		$	60		$	35		$	17		$	17
	(PPL Energy Supply)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Land and transmission rights			$	17		$	14		$	17		$	13
		Emission allowances/RECs (a)				11						13
		Licenses and other (b)				295			39			277			35
	Total subject to amortization				$	323		$	53		$	307		$	48
	(a)       Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization.
	(b)       "Other" includes costs for the development of licenses, the most significant of which is the COLA. Amortization of these costs begins when the related asset is placed in service. See Note 8 for additional information on the COLA.
	Current intangible assets are included in "Other current assets" and long-term intangible assets are presented as "Other intangibles" on the Balance Sheets.
	Amortization expense for the years ended December 31, excluding consumption of emission allowances/RECs of $23 million, $12 million, and $16 million in 2013, 2012, and 2011 was as follows:
				2013			2012			2011
	Amortization expense		$	5		$	9		$	20
	Amortization expense and consumption of emission allowances/RECs is expected to be insignificant in future years.
(PPL Electric)
The gross carrying amount and the accumulated amortization of other intangible assets were:
				December 31, 2013						December 31, 2012
				Gross						Gross
				Carrying			Accumulated			Carrying			Accumulated
				Amount			Amortization			Amount			Amortization
Subject to amortization:
	Land and transmission rights			$	293		$	102		$	249		$	99
	Licenses and other				5			1			4			1
Total subject to amortization					298			103			253			100
Not subject to amortization due to indefinite life:
	Land and transmission rights				16						18
Total				$	314		$	103		$	271		$	100
Intangible assets are shown as "Intangibles" on the Balance Sheets.
Amortization expense was insignificant in 2013, 2012 and 2011 and is expected to be insignificant in future years.
(LKE)
The gross carrying amount and the accumulated amortization of other intangible assets were:
				December 31, 2013						December 31, 2012
				Gross						Gross
				Carrying			Accumulated			Carrying			Accumulated
				Amount			Amortization			Amount			Amortization
Subject to amortization:
	Coal contracts (a)			$	269		$	171		$	269		$	128
	Land and transmission rights				20			2			18			1
	Emission allowances (b)				4						4
	OVEC power purchase agreement (c)				126			25			126			17
Total subject to amortization				$	419		$	198		$	417		$	146
(a)       Gross carrying amount represents 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)       Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
(c)       Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. 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, excluding consumption of emission allowances, was as follows:
			2013			2012			2011
Intangible assets with no regulatory offset		$	1					$	1
Intangible assets with regulatory offset			51		$	47			87
Total		$	52		$	47		$	88
Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be:
			2014			2015			2016			2017			2018
Intangible assets with regulatory offset		$	48		$	50		$	27		$	9		$	9
(LG&E)
The gross carrying amount and the accumulated amortization of other intangible assets were:
				December 31, 2013						December 31, 2012
				Gross						Gross
				Carrying			Accumulated			Carrying			Accumulated
				Amount			Amortization			Amount			Amortization
Subject to amortization:
	Coal contracts (a)			$	124		$	81		$	124		$	62
	Land and transmission rights				7			1			8			1
	Emission allowances (b)				1						1
	OVEC power purchase agreement (c)				87			17			87			13
Total subject to amortization				$	219		$	99		$	220		$	76
(a)       Gross carrying amount represents 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)       Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
(c)       Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. 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, excluding consumption of emission allowances, was as follows:
			2013			2012			2011
Intangible assets with no regulatory offset								$	1
Intangible assets with regulatory offset		$	23		$	23			45
Total		$	23		$	23		$	46
Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be:
			2014			2015			2016			2017			2018
Intangible assets with regulatory offset		$	23		$	24		$	13		$	6		$	6
(KU)
The gross carrying amount and the accumulated amortization of other intangible assets were:
				December 31, 2013						December 31, 2012
				Gross						Gross
				Carrying			Accumulated			Carrying			Accumulated
				Amount			Amortization			Amount			Amortization
Subject to amortization:
	Coal contracts (a)			$	145		$	90		$	145		$	66
	Land and transmission rights				13			1			10
	Emission allowances (b)				3						3
	OVEC power purchase agreement (c)				39			8			39			4
Total subject to amortization				$	200		$	99		$	197		$	70
(a)       Gross carrying amount represents 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)       Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
(c)       Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. 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, excluding consumption of emission allowances, was as follows:
			2013			2012			2011
Intangible assets with no regulatory offset		$	1
Intangible assets with regulatory offset			28		$	24		$	42
Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be:
			2014			2015			2016			2017			2018
Intangible assets with regulatory offset		$	24		$	26		$	13		$	3		$	3

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'
Asset Retirement Obligations	'
	21. 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 Energy Supply)
	PPL Energy Supply has recorded AROs to reflect various legal obligations associated with the retirement of long-lived assets, the most significant of which relates to the decommissioning of the Susquehanna nuclear plant. The accrued nuclear decommissioning obligation was $342 million and $316 million at December 31, 2013 and 2012. The fair value of investments that are legally restricted for the decommissioning of the Susquehanna nuclear plant was $864 million and $712 million at December 31, 2013 and 2012, and is included in "Nuclear plant decommissioning trust funds" on the Balance Sheets. See Notes 18 and 23 for additional information on the nuclear decommissioning trust funds. Other AROs recorded relate to various environmental requirements for coal piles, ash basins and other waste basin retirements.
	PPL Energy Supply has recorded several conditional AROs, the most significant of which related to the removal and disposal of asbestos-containing material. In addition to the AROs that were recorded for asbestos-containing material, PPL Energy Supply identified other asbestos-related obligations, but was unable to reasonably estimate their fair values. PPL Energy Supply management was unable to reasonably estimate a settlement date or range of settlement dates for the remediation of all of the asbestos-containing material at certain of the generation plants. If economic events or other circumstances change that enable PPL Energy Supply to reasonably estimate the fair value of these retirement obligations, they will be recorded at that time.
	PPL Energy Supply also identified legal retirement obligations associated with the retirement of a reservoir that could not be reasonably estimated due to an indeterminable settlement date.
	(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 associated 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 removal 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. In 2013, AROs were revalued primarily due to updates in the estimated cash flows for ash ponds and CCR surface impoundments based on updated cost estimates.
	(All Registrants except PPL Electric)
	The changes in the carrying amounts of AROs were as follows.
				PPL				PPL Energy Supply
				2013		2012		2013		2012
	ARO at beginning of period			$	552	$	497	$	375	$	359
		Accretion expense			38		36		29		28
		Obligations incurred			6		9		6		3
		Changes in estimated cash flow or settlement date			123		31		1		-7
		Effect of foreign currency exchange rates			1		1
		Obligations settled			-15		-22		-7		-8
	ARO at end of period			$	705	$	552	$	404	$	375
				LKE				LG&E				KU
				2013		2012		2013		2012		2013		2012
	ARO at beginning of period			$	131	$	118	$	62	$	57	$	69	$	61
		Accretion expense			7		6		3		3		4		3
		Obligations incurred					6								6
		Changes in estimated cash flow
			or settlement date		122		15		17		5		105		10
		Obligations settled			-8		-14		-8		-3				-11
	ARO at end of period			$	252	$	131	$	74	$	62	$	178	$	69
	Substantially all of the ARO balances are classified as noncurrent at December 31, 2013 and 2012.

Variable_Interest_Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2013
Variable Interest Entities [Line Items]	'
Variable Interest Entities	'
	22. Variable Interest Entities
	(PPL and PPL Energy Supply)
	In December 2001, a subsidiary of PPL Energy Supply entered into a $455 million operating lease arrangement, as lessee, for the development, construction and operation of a gas-fired combined-cycle generation facility located in Lower Mt. Bethel Township, Northampton County, Pennsylvania. The owner/lessor of this generation facility, LMB Funding, LP, was created to own/lease the facility and incur the related financing costs. The initial lease term commenced on the date of commercial operation, which occurred in May 2004, and ended in December 2013. Under a residual value guarantee, if the generation facility was sold at the end of the lease term and the cash proceeds from the sale were less than the original acquisition cost, the subsidiary of PPL Energy Supply was obligated to pay up to 70.52% of the original acquisition cost. This residual value guarantee protected the other variable interest holders from losses related to their investments. LMB Funding, LP could not extend or cancel the lease or sell the facility without the prior consent of the PPL Energy Supply subsidiary. As a result, LMB Funding, LP was determined to be a VIE and the subsidiary of PPL Energy Supply was considered the primary beneficiary that consolidated this VIE.
	The lease financing, which included $437 million of debt and $18 million of "Noncontrolling interests" was secured by, among other things, the generation facility, the carrying amount of which is disclosed on the Balance Sheet. As a result of the consolidation, PPL Energy Supply recorded interest expense in lieu of rent expense. For 2013, 2012 and 2011, additional depreciation on the generation facility of $12 million, $16 million and $16 million was recorded.
	A subsidiary of PPL Energy Supply purchased the Lower Mt. Bethel plant for $455 million at the lease termination date in December 2013. The proceeds were used by LMB Funding, LP to repay $437 million of outstanding debt and make an $18 million distribution to its equity investors both of which have been included in the PPL and PPL Energy Supply Consolidated Statements of Cash Flows as financing activities. The transaction was treated as a transfer of assets between entities under common control and did not result in any change to the presentation of the Lower Mt. Bethel plant assets as they had previously been included in PPL's and PPL Energy Supply's consolidated financial statements.
	Subsequent to these transactions, the PPL Energy Supply subsidiary no longer has a variable interest in and is no longer the primary beneficiary of LMB Funding, LP. Accordingly, LMB Funding, LP was deconsolidated, which had no impact on PPL's and PPL Energy Supply's consolidated financial statements.
PPL Energy Supply LLC [Member]	'
Variable Interest Entities [Line Items]	'
Variable Interest Entities	'
	22. Variable Interest Entities
	(PPL and PPL Energy Supply)
	In December 2001, a subsidiary of PPL Energy Supply entered into a $455 million operating lease arrangement, as lessee, for the development, construction and operation of a gas-fired combined-cycle generation facility located in Lower Mt. Bethel Township, Northampton County, Pennsylvania. The owner/lessor of this generation facility, LMB Funding, LP, was created to own/lease the facility and incur the related financing costs. The initial lease term commenced on the date of commercial operation, which occurred in May 2004, and ended in December 2013. Under a residual value guarantee, if the generation facility was sold at the end of the lease term and the cash proceeds from the sale were less than the original acquisition cost, the subsidiary of PPL Energy Supply was obligated to pay up to 70.52% of the original acquisition cost. This residual value guarantee protected the other variable interest holders from losses related to their investments. LMB Funding, LP could not extend or cancel the lease or sell the facility without the prior consent of the PPL Energy Supply subsidiary. As a result, LMB Funding, LP was determined to be a VIE and the subsidiary of PPL Energy Supply was considered the primary beneficiary that consolidated this VIE.
	The lease financing, which included $437 million of debt and $18 million of "Noncontrolling interests" was secured by, among other things, the generation facility, the carrying amount of which is disclosed on the Balance Sheet. As a result of the consolidation, PPL Energy Supply recorded interest expense in lieu of rent expense. For 2013, 2012 and 2011, additional depreciation on the generation facility of $12 million, $16 million and $16 million was recorded.
	A subsidiary of PPL Energy Supply purchased the Lower Mt. Bethel plant for $455 million at the lease termination date in December 2013. The proceeds were used by LMB Funding, LP to repay $437 million of outstanding debt and make an $18 million distribution to its equity investors both of which have been included in the PPL and PPL Energy Supply Consolidated Statements of Cash Flows as financing activities. The transaction was treated as a transfer of assets between entities under common control and did not result in any change to the presentation of the Lower Mt. Bethel plant assets as they had previously been included in PPL's and PPL Energy Supply's consolidated financial statements.
	Subsequent to these transactions, the PPL Energy Supply subsidiary no longer has a variable interest in and is no longer the primary beneficiary of LMB Funding, LP. Accordingly, LMB Funding, LP was deconsolidated, which had no impact on PPL's and PPL Energy Supply's consolidated financial statements.

AvailableforSale_Securities

Available-for-Sale Securities	12 Months Ended
	Dec. 31, 2013
Available-for-Sale Securities [Line Items]	'
Available-for-Sale Securities	'
	23. Available-for-Sale Securities
	(PPL and PPL Energy Supply)
	Securities held by the NDT funds and auction rate securities are classified as available-for-sale.
	The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of available-for-sale securities.
							December 31, 2013											December 31, 2012
										Gross			Gross							Gross		Gross
							Amortized			Unrealized			Unrealized					Amortized		Unrealized		Unrealized
							Cost			Gains			Losses			Fair Value		Cost		Gains		Losses		Fair Value
	NDT funds:
	PPL and PPL Energy Supply
			Cash and cash equivalents				$	14								$	14	$	11					$	11
			Equity securities					265		$	363						628		252	$	220				472
			Debt securities					217			7		$	3			221		211		19	$	1		229
			Receivables/payables, net					1									1
			Total NDT funds				$	497		$	370		$	3		$	864	$	474	$	239	$	1	$	712
	Auction rate securities:
		PPL					$	20					$	1		$	19	$	20			$	1	$	19
		PPL Energy Supply						17						1			16		17				1		16
	See Note 18 for details on the securities held by the NDT funds.
	There were no securities with credit losses at December 31, 2013 and 2012.
	The following table shows the scheduled maturity dates of debt securities held at December 31, 2013.
				Maturity		Maturity			Maturity			Maturity
				Less Than		5-Jan			10-Jun			in Excess
				1 Year		Years			Years			of 10 Years			Total
	PPL
	Amortized cost			$	7	$	97		$	54		$	79		$	237
	Fair value				7		99			55			79			240
	PPL Energy Supply
	Amortized cost			$	7	$	97		$	54		$	76		$	234
	Fair value				7		99			55			76			237
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities.
				2013		2012			2011
	PPL
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						5			163
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	PPL Energy Supply
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						3
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	(a)       These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
	(b)       Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.
	Short-term Investments (PPL, LKE and LG&E)
	At December 31, 2010, LG&E held $163 million aggregate principal amount of tax-exempt revenue bonds issued by Louisville/Jefferson County, Kentucky on behalf of LG&E that were purchased from the remarketing agent in 2008. In 2011, LG&E received $163 million for its investments in these bonds when they were remarketed to unaffiliated investors. No realized or unrealized gains (losses) were recorded on these securities, as the difference between carrying value and fair value was not significant.
	NDT Funds (PPL and PPL Energy Supply)
	Amounts previously collected from PPL Electric's customers for decommissioning the Susquehanna nuclear plant, less applicable taxes, were deposited in external trust funds for investment and can only be used for future decommissioning costs. To the extent that the actual costs for decommissioning exceed the amounts in the nuclear decommissioning trust funds, PPL Susquehanna would be obligated to fund 90% of the shortfall.
	When the fair value of a security is less than amortized cost, PPL and PPL Energy Supply must make certain assertions to avoid recording an other-than-temporary impairment that requires a current period charge to earnings. The NRC requires that nuclear decommissioning trusts be managed by independent investment managers, with discretion to buy and sell securities in the trusts. As a result, PPL and PPL Energy Supply have been unable to demonstrate the ability to hold an impaired security until it recovers its value; therefore, unrealized losses on equity securities for all periods presented, represented other-than-temporary impairments that required a current period charge to earnings. PPL and PPL Energy Supply recorded impairments for certain securities invested in the NDT funds of $6 million for 2011. The amounts for 2013 and 2012 are insignificant. These impairments are reflected on the Statements of Income in "Other-Than-Temporary Impairments."
PPL Energy Supply LLC [Member]	'
Available-for-Sale Securities [Line Items]	'
Available-for-Sale Securities	'
	23. Available-for-Sale Securities
	(PPL and PPL Energy Supply)
	Securities held by the NDT funds and auction rate securities are classified as available-for-sale.
	The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of available-for-sale securities.
							December 31, 2013											December 31, 2012
										Gross			Gross							Gross		Gross
							Amortized			Unrealized			Unrealized					Amortized		Unrealized		Unrealized
							Cost			Gains			Losses			Fair Value		Cost		Gains		Losses		Fair Value
	NDT funds:
	PPL and PPL Energy Supply
			Cash and cash equivalents				$	14								$	14	$	11					$	11
			Equity securities					265		$	363						628		252	$	220				472
			Debt securities					217			7		$	3			221		211		19	$	1		229
			Receivables/payables, net					1									1
			Total NDT funds				$	497		$	370		$	3		$	864	$	474	$	239	$	1	$	712
	Auction rate securities:
		PPL					$	20					$	1		$	19	$	20			$	1	$	19
		PPL Energy Supply						17						1			16		17				1		16
	See Note 18 for details on the securities held by the NDT funds.
	There were no securities with credit losses at December 31, 2013 and 2012.
	The following table shows the scheduled maturity dates of debt securities held at December 31, 2013.
				Maturity		Maturity			Maturity			Maturity
				Less Than		5-Jan			10-Jun			in Excess
				1 Year		Years			Years			of 10 Years			Total
	PPL
	Amortized cost			$	7	$	97		$	54		$	79		$	237
	Fair value				7		99			55			79			240
	PPL Energy Supply
	Amortized cost			$	7	$	97		$	54		$	76		$	234
	Fair value				7		99			55			76			237
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities.
				2013		2012			2011
	PPL
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						5			163
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	PPL Energy Supply
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						3
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	(a)       These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
	(b)       Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.
	Short-term Investments (PPL, LKE and LG&E)
	At December 31, 2010, LG&E held $163 million aggregate principal amount of tax-exempt revenue bonds issued by Louisville/Jefferson County, Kentucky on behalf of LG&E that were purchased from the remarketing agent in 2008. In 2011, LG&E received $163 million for its investments in these bonds when they were remarketed to unaffiliated investors. No realized or unrealized gains (losses) were recorded on these securities, as the difference between carrying value and fair value was not significant.
	NDT Funds (PPL and PPL Energy Supply)
	Amounts previously collected from PPL Electric's customers for decommissioning the Susquehanna nuclear plant, less applicable taxes, were deposited in external trust funds for investment and can only be used for future decommissioning costs. To the extent that the actual costs for decommissioning exceed the amounts in the nuclear decommissioning trust funds, PPL Susquehanna would be obligated to fund 90% of the shortfall.
	When the fair value of a security is less than amortized cost, PPL and PPL Energy Supply must make certain assertions to avoid recording an other-than-temporary impairment that requires a current period charge to earnings. The NRC requires that nuclear decommissioning trusts be managed by independent investment managers, with discretion to buy and sell securities in the trusts. As a result, PPL and PPL Energy Supply have been unable to demonstrate the ability to hold an impaired security until it recovers its value; therefore, unrealized losses on equity securities for all periods presented, represented other-than-temporary impairments that required a current period charge to earnings. PPL and PPL Energy Supply recorded impairments for certain securities invested in the NDT funds of $6 million for 2011. The amounts for 2013 and 2012 are insignificant. These impairments are reflected on the Statements of Income in "Other-Than-Temporary Impairments."
LG And E And KU Energy LLC [Member]	'
Available-for-Sale Securities [Line Items]	'
Available-for-Sale Securities	'
	23. Available-for-Sale Securities
	(PPL and PPL Energy Supply)
	Securities held by the NDT funds and auction rate securities are classified as available-for-sale.
	The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of available-for-sale securities.
							December 31, 2013											December 31, 2012
										Gross			Gross							Gross		Gross
							Amortized			Unrealized			Unrealized					Amortized		Unrealized		Unrealized
							Cost			Gains			Losses			Fair Value		Cost		Gains		Losses		Fair Value
	NDT funds:
	PPL and PPL Energy Supply
			Cash and cash equivalents				$	14								$	14	$	11					$	11
			Equity securities					265		$	363						628		252	$	220				472
			Debt securities					217			7		$	3			221		211		19	$	1		229
			Receivables/payables, net					1									1
			Total NDT funds				$	497		$	370		$	3		$	864	$	474	$	239	$	1	$	712
	Auction rate securities:
		PPL					$	20					$	1		$	19	$	20			$	1	$	19
		PPL Energy Supply						17						1			16		17				1		16
	See Note 18 for details on the securities held by the NDT funds.
	There were no securities with credit losses at December 31, 2013 and 2012.
	The following table shows the scheduled maturity dates of debt securities held at December 31, 2013.
				Maturity		Maturity			Maturity			Maturity
				Less Than		5-Jan			10-Jun			in Excess
				1 Year		Years			Years			of 10 Years			Total
	PPL
	Amortized cost			$	7	$	97		$	54		$	79		$	237
	Fair value				7		99			55			79			240
	PPL Energy Supply
	Amortized cost			$	7	$	97		$	54		$	76		$	234
	Fair value				7		99			55			76			237
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities.
				2013		2012			2011
	PPL
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						5			163
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	PPL Energy Supply
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						3
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	(a)       These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
	(b)       Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.
	Short-term Investments (PPL, LKE and LG&E)
	At December 31, 2010, LG&E held $163 million aggregate principal amount of tax-exempt revenue bonds issued by Louisville/Jefferson County, Kentucky on behalf of LG&E that were purchased from the remarketing agent in 2008. In 2011, LG&E received $163 million for its investments in these bonds when they were remarketed to unaffiliated investors. No realized or unrealized gains (losses) were recorded on these securities, as the difference between carrying value and fair value was not significant.
	NDT Funds (PPL and PPL Energy Supply)
	Amounts previously collected from PPL Electric's customers for decommissioning the Susquehanna nuclear plant, less applicable taxes, were deposited in external trust funds for investment and can only be used for future decommissioning costs. To the extent that the actual costs for decommissioning exceed the amounts in the nuclear decommissioning trust funds, PPL Susquehanna would be obligated to fund 90% of the shortfall.
	When the fair value of a security is less than amortized cost, PPL and PPL Energy Supply must make certain assertions to avoid recording an other-than-temporary impairment that requires a current period charge to earnings. The NRC requires that nuclear decommissioning trusts be managed by independent investment managers, with discretion to buy and sell securities in the trusts. As a result, PPL and PPL Energy Supply have been unable to demonstrate the ability to hold an impaired security until it recovers its value; therefore, unrealized losses on equity securities for all periods presented, represented other-than-temporary impairments that required a current period charge to earnings. PPL and PPL Energy Supply recorded impairments for certain securities invested in the NDT funds of $6 million for 2011. The amounts for 2013 and 2012 are insignificant. These impairments are reflected on the Statements of Income in "Other-Than-Temporary Impairments."
Louisville Gas And Electric Co [Member]	'
Available-for-Sale Securities [Line Items]	'
Available-for-Sale Securities	'
	23. Available-for-Sale Securities
	(PPL and PPL Energy Supply)
	Securities held by the NDT funds and auction rate securities are classified as available-for-sale.
	The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of available-for-sale securities.
							December 31, 2013											December 31, 2012
										Gross			Gross							Gross		Gross
							Amortized			Unrealized			Unrealized					Amortized		Unrealized		Unrealized
							Cost			Gains			Losses			Fair Value		Cost		Gains		Losses		Fair Value
	NDT funds:
	PPL and PPL Energy Supply
			Cash and cash equivalents				$	14								$	14	$	11					$	11
			Equity securities					265		$	363						628		252	$	220				472
			Debt securities					217			7		$	3			221		211		19	$	1		229
			Receivables/payables, net					1									1
			Total NDT funds				$	497		$	370		$	3		$	864	$	474	$	239	$	1	$	712
	Auction rate securities:
		PPL					$	20					$	1		$	19	$	20			$	1	$	19
		PPL Energy Supply						17						1			16		17				1		16
	See Note 18 for details on the securities held by the NDT funds.
	There were no securities with credit losses at December 31, 2013 and 2012.
	The following table shows the scheduled maturity dates of debt securities held at December 31, 2013.
				Maturity		Maturity			Maturity			Maturity
				Less Than		5-Jan			10-Jun			in Excess
				1 Year		Years			Years			of 10 Years			Total
	PPL
	Amortized cost			$	7	$	97		$	54		$	79		$	237
	Fair value				7		99			55			79			240
	PPL Energy Supply
	Amortized cost			$	7	$	97		$	54		$	76		$	234
	Fair value				7		99			55			76			237
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities.
				2013		2012			2011
	PPL
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						5			163
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	PPL Energy Supply
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						3
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	(a)       These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
	(b)       Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.
	Short-term Investments (PPL, LKE and LG&E)
	At December 31, 2010, LG&E held $163 million aggregate principal amount of tax-exempt revenue bonds issued by Louisville/Jefferson County, Kentucky on behalf of LG&E that were purchased from the remarketing agent in 2008. In 2011, LG&E received $163 million for its investments in these bonds when they were remarketed to unaffiliated investors. No realized or unrealized gains (losses) were recorded on these securities, as the difference between carrying value and fair value was not significant.
	NDT Funds (PPL and PPL Energy Supply)
	Amounts previously collected from PPL Electric's customers for decommissioning the Susquehanna nuclear plant, less applicable taxes, were deposited in external trust funds for investment and can only be used for future decommissioning costs. To the extent that the actual costs for decommissioning exceed the amounts in the nuclear decommissioning trust funds, PPL Susquehanna would be obligated to fund 90% of the shortfall.
	When the fair value of a security is less than amortized cost, PPL and PPL Energy Supply must make certain assertions to avoid recording an other-than-temporary impairment that requires a current period charge to earnings. The NRC requires that nuclear decommissioning trusts be managed by independent investment managers, with discretion to buy and sell securities in the trusts. As a result, PPL and PPL Energy Supply have been unable to demonstrate the ability to hold an impaired security until it recovers its value; therefore, unrealized losses on equity securities for all periods presented, represented other-than-temporary impairments that required a current period charge to earnings. PPL and PPL Energy Supply recorded impairments for certain securities invested in the NDT funds of $6 million for 2011. The amounts for 2013 and 2012 are insignificant. These impairments are reflected on the Statements of Income in "Other-Than-Temporary Impairments."

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated Other Comprehensive Income (Loss)	'
	24. Accumulated Other Comprehensive Income (Loss)
	(PPL, PPL Energy Supply and LKE)
	AOCI, which is presented on the Balance Sheet of PPL and included in Member's equity on the Balance Sheets of PPL Energy Supply and LKE, consisted of the following after-tax gains (losses).
						Unrealized gains (losses)									Defined benefit plans
			Foreign
			currency			Available-						Equity			Prior			Actuarial			Transition
			translation			for-sale			Qualifying			investees'			service			gain			asset
			adjustments			securities			derivatives			AOCI			costs			(loss)			(obligation)			Total
	PPL
	December 31, 2010		$	-195		$	88		$	695		$	-4		$	-32		$	-1,032		$	1		$	-479
	OCI			-48			2			-168			3			7			-105						-309
	December 31, 2011		$	-243		$	90		$	527		$	-1		$	-25		$	-1,137		$	1		$	-788
	OCI			94			22			-395			2			11			-886						-1,152
	December 31, 2012		$	-149		$	112		$	132		$	1		$	-14		$	-2,023		$	1		$	-1,940
	Amounts arising during the period			138			67			45						2			71						323
	Reclassifications from AOCI						-6			-83						6			135						52
	Net OCI during the period			138			61			-38						8			206						375
	December 31, 2013		$	-11		$	173		$	94		$	1		$	-6		$	-1,817		$	1		$	-1,565
	PPL Energy Supply
	December 31, 2010		$	-195		$	88		$	733		$	-3		$	-23		$	-955					$	-355
	OCI						2			-86			3			2			-18						-97
	Distribution of membership
		interest in PPL Global (a)		195						-41						5			780						939
	December 31, 2011					$	90		$	606		$			$	-16		$	-193					$	487
	OCI						22			-395						6			-72						-439
	December 31, 2012		$			$	112		$	211		$			$	-10		$	-265					$	48
	Amounts arising during the period						67									2			71						140
	Reclassifications from AOCI						-6			-123						4			14						-111
	Net OCI during the period						61			-123						6			85						29
	December 31, 2013		$			$	173		$	88		$			$	-4		$	-180					$	77
	LKE
	December 31, 2010																	$	6					$	6
	OCI														$	-2									-2
	December 31, 2011														$	-2		$	6					$	4
	OCI											$	1						-20						-19
	December 31, 2012											$	1		$	-2		$	-14					$	-15
	Amounts arising during the period																		28						28
	Net OCI during the period																		28						28
	December 31, 2013											$	1		$	-2		$	14					$	13
	(a)       See Note 9 for additional information.
	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the year ended December 31, 2013. 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). See Note 13 for additional information.
				Affected Line Item on the Statements of Income
													Other
				Unregulated									Income
				wholesale			Energy			Interest			(Expense),						Total			Income			Total
	Details about AOCI			energy			purchases			Expense			net			Other			Pre-tax			Taxes			After-tax
	PPL
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Interest rate swaps								$	-20									-20			1			-19
		Cross-currency swaps									1			-28						-27			4			-23
		Energy commodities		$	263		$	-58								$	5			210			-85			125
		Total		$	263		$	-58		$	-19		$	-28		$	5			163			-80			83
	Defined benefit plans
		Prior service costs																		-10			4			-6
		Net actuarial loss																		-184			49			-135
		Total																	$	-194		$	53			-141
	Total reclassifications																								$	-52
	PPL Energy Supply
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Energy commodities		$	263		$	-58								$	2			207			-84			123
	Defined benefit plans
	Prior service costs																		-7			3			-4
	Net actuarial loss																		-24			10			-14
	Total																	$	-31		$	13			-18
Total reclassifications																								$	111
PPL Energy Supply LLC [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated Other Comprehensive Income (Loss)	'
	24. Accumulated Other Comprehensive Income (Loss)
	(PPL, PPL Energy Supply and LKE)
	AOCI, which is presented on the Balance Sheet of PPL and included in Member's equity on the Balance Sheets of PPL Energy Supply and LKE, consisted of the following after-tax gains (losses).
						Unrealized gains (losses)									Defined benefit plans
			Foreign
			currency			Available-						Equity			Prior			Actuarial			Transition
			translation			for-sale			Qualifying			investees'			service			gain			asset
			adjustments			securities			derivatives			AOCI			costs			(loss)			(obligation)			Total
	PPL
	December 31, 2010		$	-195		$	88		$	695		$	-4		$	-32		$	-1,032		$	1		$	-479
	OCI			-48			2			-168			3			7			-105						-309
	December 31, 2011		$	-243		$	90		$	527		$	-1		$	-25		$	-1,137		$	1		$	-788
	OCI			94			22			-395			2			11			-886						-1,152
	December 31, 2012		$	-149		$	112		$	132		$	1		$	-14		$	-2,023		$	1		$	-1,940
	Amounts arising during the period			138			67			45						2			71						323
	Reclassifications from AOCI						-6			-83						6			135						52
	Net OCI during the period			138			61			-38						8			206						375
	December 31, 2013		$	-11		$	173		$	94		$	1		$	-6		$	-1,817		$	1		$	-1,565
	PPL Energy Supply
	December 31, 2010		$	-195		$	88		$	733		$	-3		$	-23		$	-955					$	-355
	OCI						2			-86			3			2			-18						-97
	Distribution of membership
		interest in PPL Global (a)		195						-41						5			780						939
	December 31, 2011					$	90		$	606		$			$	-16		$	-193					$	487
	OCI						22			-395						6			-72						-439
	December 31, 2012		$			$	112		$	211		$			$	-10		$	-265					$	48
	Amounts arising during the period						67									2			71						140
	Reclassifications from AOCI						-6			-123						4			14						-111
	Net OCI during the period						61			-123						6			85						29
	December 31, 2013		$			$	173		$	88		$			$	-4		$	-180					$	77
	LKE
	December 31, 2010																	$	6					$	6
	OCI														$	-2									-2
	December 31, 2011														$	-2		$	6					$	4
	OCI											$	1						-20						-19
	December 31, 2012											$	1		$	-2		$	-14					$	-15
	Amounts arising during the period																		28						28
	Net OCI during the period																		28						28
	December 31, 2013											$	1		$	-2		$	14					$	13
	(a)       See Note 9 for additional information.
	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the year ended December 31, 2013. 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). See Note 13 for additional information.
				Affected Line Item on the Statements of Income
													Other
				Unregulated									Income
				wholesale			Energy			Interest			(Expense),						Total			Income			Total
	Details about AOCI			energy			purchases			Expense			net			Other			Pre-tax			Taxes			After-tax
	PPL
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Interest rate swaps								$	-20									-20			1			-19
		Cross-currency swaps									1			-28						-27			4			-23
		Energy commodities		$	263		$	-58								$	5			210			-85			125
		Total		$	263		$	-58		$	-19		$	-28		$	5			163			-80			83
	Defined benefit plans
		Prior service costs																		-10			4			-6
		Net actuarial loss																		-184			49			-135
		Total																	$	-194		$	53			-141
	Total reclassifications																								$	-52
	PPL Energy Supply
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Energy commodities		$	263		$	-58								$	2			207			-84			123
	Defined benefit plans
	Prior service costs																		-7			3			-4
	Net actuarial loss																		-24			10			-14
	Total																	$	-31		$	13			-18
Total reclassifications																								$	111
LG And E And KU Energy LLC [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated Other Comprehensive Income (Loss)	'
	24. Accumulated Other Comprehensive Income (Loss)
	(PPL, PPL Energy Supply and LKE)
	AOCI, which is presented on the Balance Sheet of PPL and included in Member's equity on the Balance Sheets of PPL Energy Supply and LKE, consisted of the following after-tax gains (losses).
						Unrealized gains (losses)									Defined benefit plans
			Foreign
			currency			Available-						Equity			Prior			Actuarial			Transition
			translation			for-sale			Qualifying			investees'			service			gain			asset
			adjustments			securities			derivatives			AOCI			costs			(loss)			(obligation)			Total
	PPL
	December 31, 2010		$	-195		$	88		$	695		$	-4		$	-32		$	-1,032		$	1		$	-479
	OCI			-48			2			-168			3			7			-105						-309
	December 31, 2011		$	-243		$	90		$	527		$	-1		$	-25		$	-1,137		$	1		$	-788
	OCI			94			22			-395			2			11			-886						-1,152
	December 31, 2012		$	-149		$	112		$	132		$	1		$	-14		$	-2,023		$	1		$	-1,940
	Amounts arising during the period			138			67			45						2			71						323
	Reclassifications from AOCI						-6			-83						6			135						52
	Net OCI during the period			138			61			-38						8			206						375
	December 31, 2013		$	-11		$	173		$	94		$	1		$	-6		$	-1,817		$	1		$	-1,565
	PPL Energy Supply
	December 31, 2010		$	-195		$	88		$	733		$	-3		$	-23		$	-955					$	-355
	OCI						2			-86			3			2			-18						-97
	Distribution of membership
		interest in PPL Global (a)		195						-41						5			780						939
	December 31, 2011					$	90		$	606		$			$	-16		$	-193					$	487
	OCI						22			-395						6			-72						-439
	December 31, 2012		$			$	112		$	211		$			$	-10		$	-265					$	48
	Amounts arising during the period						67									2			71						140
	Reclassifications from AOCI						-6			-123						4			14						-111
	Net OCI during the period						61			-123						6			85						29
	December 31, 2013		$			$	173		$	88		$			$	-4		$	-180					$	77
	LKE
	December 31, 2010																	$	6					$	6
	OCI														$	-2									-2
	December 31, 2011														$	-2		$	6					$	4
	OCI											$	1						-20						-19
	December 31, 2012											$	1		$	-2		$	-14					$	-15
	Amounts arising during the period																		28						28
	Net OCI during the period																		28						28
	December 31, 2013											$	1		$	-2		$	14					$	13
	(a)       See Note 9 for additional information.
	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the year ended December 31, 2013. 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). See Note 13 for additional information.
				Affected Line Item on the Statements of Income
													Other
				Unregulated									Income
				wholesale			Energy			Interest			(Expense),						Total			Income			Total
	Details about AOCI			energy			purchases			Expense			net			Other			Pre-tax			Taxes			After-tax
	PPL
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Interest rate swaps								$	-20									-20			1			-19
		Cross-currency swaps									1			-28						-27			4			-23
		Energy commodities		$	263		$	-58								$	5			210			-85			125
		Total		$	263		$	-58		$	-19		$	-28		$	5			163			-80			83
	Defined benefit plans
		Prior service costs																		-10			4			-6
		Net actuarial loss																		-184			49			-135
		Total																	$	-194		$	53			-141
	Total reclassifications																								$	-52
	PPL Energy Supply
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Energy commodities		$	263		$	-58								$	2			207			-84			123
	Defined benefit plans
	Prior service costs																		-7			3			-4
	Net actuarial loss																		-24			10			-14
	Total																	$	-31		$	13			-18
Total reclassifications																								$	111

New_Accounting_Guidance_Pendin

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2013
New Accounting Guidance Pending Adoption [Abstract]	'
New Accounting Guidance Pending Adoption	'
	25. New Accounting Guidance Pending Adoption
	(All Registrants)
	Accounting for Obligations Resulting from Joint and Several Liability Arrangements
	Effective January 1, 2014, the Registrants will retrospectively adopt accounting guidance for the recognition, measurement and disclosure of certain obligations resulting from joint and several liability arrangements when the amount of the obligation is fixed at the reporting date. If the obligation is determined to be in the scope of this guidance, it will be measured as the sum of the amount the reporting entity agreed to pay on the basis of its arrangements among its co-obligors and any additional amount the reporting entity expects to pay on behalf of its co-obligors. This guidance also requires additional disclosures for these obligations.
	The adoption of this guidance is not expected to have a significant impact on the Registrants.
	Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity
	Effective January 1, 2014, PPL will prospectively adopt accounting guidance that requires a cumulative translation adjustment to be released into earnings when an entity ceases to have a controlling financial interest in a subsidiary or group of assets within a consolidated foreign entity and the sale or transfer results in the complete or substantially complete liquidation of the foreign entity. For the step acquisition of previously held equity method investments that are foreign entities, this guidance clarifies that the amount of accumulated other comprehensive income that is reclassified and included in the calculation of a gain or loss shall include any foreign currency translation adjustment related to that previously held investment.
	The initial adoption of this guidance is not expected to have a significant impact on PPL; however, the impact in future periods could be material.
	Presentation of Unrecognized Tax Benefits When Net Operating Loss Carryforwards, Similar Tax Losses, or Tax Credit Carryforwards Exist
	Effective January 1, 2014, the Registrants will prospectively adopt accounting guidance that requires an unrecognized tax benefit, or a portion of an unrecognized tax benefit, to be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward. To the extent a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position, or the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purpose, the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets.
	The adoption of this guidance is not expected to have a significant impact on the Registrants.

SCHEDULE_I_CONDENSED_UNCONSOLI

SCHEDULE I - CONDENSED UNCONSOLICATED FINANCIAL STATEMENTS AND NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS (L G And E And K U Energy L L C Unconsolidated [Member])	12 Months Ended
	Dec. 31, 2013
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)
				2013		2012		2011
	Operating Revenues
	Operating Expenses
		Other operation and maintenance				$	3
		Total Operating Expenses					3
	Operating Income (Loss)						-3
	Equity in Earnings of Subsidiaries			$	376		234	$	267
	Interest Income with Affiliate				5		10		29
	Interest Expense				39		39		31
	Interest Expense with Affiliate				3		2		2
	Income (Loss) Before Income Taxes				339		200		263
	Income Tax Expense (Benefit)				-8		-19		-2
	Net Income (Loss) Attributable to Member			$	347	$	219	$	265
	Comprehensive Income (Loss) Attributable to Member			$	375	$	200	$	263
	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)
				2013		2012		2011
	Cash Flows from Operating Activities
	Net cash provided by (used in) operating activities			$	136	$	364	$	346
	Cash Flows from Investing Activities
			Capital contributions to affiliated subsidiaries		-243
			Net decrease (increase) in notes receivable from affiliates		-122		-15		-63
	Net cash provided by (used in) investing activities				-365		-15		-63
	Cash Flows from Financing Activities
			Net increase (decrease) in notes payable with affiliates		171		-196
			Net increase (decrease) in short-term debt		75
			Issuance of long-term debt						250
			Contribution from member		243
			Distribution to member		-254		-155		-533
	Net cash provided by (used in) financing activities				235		-351		-283
	Net Increase (Decrease) in Cash and Cash Equivalents				6		-2
	Cash and Cash Equivalents at Beginning of Period						2		2
	Cash and Cash Equivalents at End of Period			$	6	$		$	2
	Supplemental disclosures of cash flow information:
	Cash Dividends Received from Affiliated Subsidiaries			$	223	$	175	$	207
	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)
				2013		2012
	Assets
	Current Assets
		Cash and cash equivalents		$	6
		Accounts receivable			2
		Accounts receivable from affiliates			11	$	4
		Notes receivable from affiliates			1,682		1,560
		Deferred income taxes			10		1
		Total Current Assets			1,711		1,565
	Investments
		Affiliated companies at equity			4,519		4,096
	Other Noncurrent Assets
		Deferred income taxes			170		184
		Other noncurrent assets			6		7
		Total Other Noncurrent Assets			176		191
	Total Assets			$	6,406	$	5,852
	Liabilities and Equity
Current Liabilities
	Short-term debt		$	75
	Notes payable to affiliates				$	25
	Accounts payable to affiliates			843		906
	Taxes			12		8
	Other current liabilities			6		6
	Total Current Liabilities			936		945
Long-term Debt
	Long-term debt			1,121		1,121
	Notes payable to affiliates			196
	Total Long-term Debt			1,317		1,121
Deferred Credits and Other Noncurrent Liabilities				3
Equity				4,150		3,786
Total Liabilities and Equity			$	6,406	$	5,852
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 earnings to it in the form of dividends or repayment of loans and advances from the subsidiaries. These condensed financial statements and related footnotes have been prepared in accordance with Reg. §210.12-04 of Regulation S-X. These statements should be read in conjunction with the consolidated financial statements and notes thereto of LKE.
LKE indirectly or directly owns all of the ownership interests of its significant subsidiaries. LKE relies primarily on dividends from its subsidiaries to fund LKE's dividends to its member and to meet its other cash requirements.
2.       Commitments and Contingencies
See Note 15 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 guarantees is the LKE guarantee covering operational, regulatory and environmental commitments 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 fall outside the cumulative cap. LKE has contested the applicability of the indemnification requirement relating to one matter presented by a counterparty under this guarantee. Another guarantee with a maximum exposure of $100 million covering other indemnifications expires in 2023. In May 2012, LKE's indemnitee received an arbitration panel's decision affecting this matter, which granted LKE's indemnitee certain rights of first refusal to purchase excess power at a market-based price rather than at an absolute fixed price. In January 2013, LKE's indemnitee commenced a proceeding in the Kentucky Court of Appeals appealing the December 2012 order of the Henderson Circuit Court, confirming the arbitration award. A decision in the appellate matter may occur during 2014. LKE believes its indemnification obligations in this matter remain subject to various uncertainties, including potential for additional legal challenges regarding the arbitration decision as well as future prices, availability and demand for the subject excess power. LKE continues to evaluate various legal and commercial options with respect to this indemnification matter. The ultimate outcomes of the WKE termination-related indemnifications cannot be predicted at this time. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum; however, LKE is not aware of formal claims under such indemnities made by any party at this time. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. In the second quarter of 2012, LKE adjusted its estimated liability for certain of these indemnifications by $9 million ($5 million after-tax), which is reflected in "Equity in Earnings of Subsidiaries" on the Statement of Income. LKE cannot predict the ultimate outcomes of such indemnification circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded.

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
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)
					31-Mar			30-Jun			Sept. 30			Dec. 31
	2013
	Operating revenues				$	2,457		$	3,450		$	3,105		$	2,848
	Operating income (e)					693			758			857			31
	Income (loss) from continuing operations after income taxes (e)					413			404			410			-98
	Income (loss) from discontinued operations								1			1
	Net income (loss) (e)					413			405			411			-98
	Net income (loss) attributable to PPL (e)					413			405			410			-98
	Income (loss) from continuing operations after income taxes available to
		PPL common shareowners: (b) (e)
			Basic EPS			0.7			0.68			0.65			-0.16
			Diluted EPS (d)			0.65			0.63			0.62			-0.16
	Net income (loss) available to PPL common shareowners: (b) (e)
			Basic EPS			0.7			0.68			0.65			-0.16
			Diluted EPS (d)			0.65			0.63			0.62			-0.16
	Dividends declared per share of common stock (c)					0.3675			0.3675			0.3675			0.3675
	Price per common share:
			High		$	31.35		$	33.55		$	32.09		$	31.79
			Low			28.64			28.44			29.03			28.95
	2012
	Operating revenues				$	4,112		$	2,549		$	2,403		$	3,222
	Operating income					1,051			572			664			822
	Income from continuing operations after income taxes					545			277			355			360
	Income (loss) from discontinued operations								-6
	Net income					545			271			355			360
	Net income attributable to PPL					541			271			355			359
	Income from continuing operations after income taxes available to
		PPL common shareowners: (b)
			Basic EPS			0.93			0.47			0.61			0.61
			Diluted EPS			0.93			0.47			0.61			0.6
	Net income available to PPL common shareowners: (b)
			Basic EPS			0.93			0.46			0.61			0.61
			Diluted EPS			0.93			0.46			0.61			0.6
	Dividends declared per share of common stock (c)					0.36			0.36			0.36			0.36
	Price per common share:
			High		$	29.85		$	28.44		$	29.98		$	30.18
			Low			27.29			26.68			27.72			27.74
	(a)       Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.
	(b)       The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.
	(c)       PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.
	(d)       As a result of a reported loss, diluted earnings per share for the three months ended December 31, 2013 exclude incremental shares as they were anti-dilutive.
	(e)       Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements 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)
				31-Mar			30-Jun			Sept. 30			Dec. 31
	2013
	Operating revenues		$	513		$	414		$	464		$	479
	Operating income			121			92			105			101
	Net income			64			45			51			49
	Net income available to PPL			64			45			51			49
	2012
	Operating revenues		$	458		$	404		$	444		$	457
	Operating income			79			63			71			81
	Net income			37			29			33			37
	Net income available to PPL			33			29			33			37
	(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_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Summary Of Significant Accounting Policies [Line Items]	'
Business and Consolidation	'
	Business and Consolidation
	(PPL)
	PPL is an energy and utility holding company that, through its subsidiaries, is primarily engaged in: 1) the regulated distribution of electricity in the U.K.; 2) the regulated generation, transmission, distribution and sale of electricity and the regulated distribution and sale of natural gas, primarily in Kentucky; 3) the regulated transmission, distribution and sale of electricity in Pennsylvania; and 4) the competitive generation and marketing of electricity in portions of the northeastern and northwestern U.S. Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global, LKE (including its principal subsidiaries, LG&E and KU), PPL Electric and PPL Energy Supply (including its principal subsidiaries, PPL EnergyPlus and PPL Generation). PPL's corporate level financing subsidiary is PPL Capital Funding.
	WPD, a subsidiary of PPL Global, through indirect wholly owned subsidiaries operates regulated distribution networks providing electricity service in the U.K. WPD serves end-users in Wales and southwest and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands) and WPD (West Midlands).
	On April 1, 2011, PPL, through its indirect, wholly owned subsidiary PPL WEM, completed its acquisition of all of the outstanding ordinary share capital of Central Networks East plc and Central Networks Limited, the sole owner of Central Networks West plc, together with certain other related assets and liabilities (collectively referred to as Central Networks and subsequently referred to as WPD Midlands), from subsidiaries of E.ON AG. WPD Midlands' operating results are included in PPL's results of operations for the full year of 2013 and 2012, but as PPL is consolidating WPD Midlands on a one-month lag, eight months of operating results are included in PPL's results of operations for 2011.
	See Note 10 for additional information regarding the acquisition of WPD Midlands.
	PPL consolidates WPD, including WPD Midlands, on a one-month lag. Material intervening 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 Energy Supply)
	PPL Energy Supply is an energy company conducting business primarily through its principal subsidiaries PPL Generation and PPL EnergyPlus. PPL Generation owns and operates a portfolio of competitive domestic power generating assets. These power plants are located in Pennsylvania and Montana and use well-diversified fuel sources including coal, uranium, natural gas, oil and water. PPL EnergyPlus sells electricity produced by PPL Generation subsidiaries, participates in wholesale market load-following auctions, and markets various energy products and commodities such as: capacity, transmission, FTRs, coal, natural gas, oil, uranium, emission allowances, RECs and other commodities in competitive wholesale and competitive retail markets, primarily in the northeastern and northwestern U.S.
	On April 13, 2012, an indirect, wholly owned subsidiary of PPL Energy Supply completed the Ironwood Acquisition. See Note 10 for additional information.
	(PPL and PPL Electric)
	PPL Electric is a cost-based rate-regulated utility subsidiary of PPL. PPL Electric's principal business is the regulated transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR.
	(PPL, LKE, LG&E and KU)
	LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, LG&E and KU. LG&E and KU are engaged in the regulated generation, transmission, distribution and sale of electricity. LG&E also engages in the regulated 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, PPL Energy Supply and LKE)
	"Income (Loss) from Discontinued Operations (net of income taxes)" on the Statements of Income includes the activities of various businesses that were sold or distributed. See Note 9 for additional information. The Statements of Cash Flows do not separately report the cash flows of the Discontinued Operations.
	(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 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. For PPL and PPL Energy Supply, see Note 22 for information regarding a previously consolidated VIE. Investments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. All significant intercompany transactions have been eliminated. Any noncontrolling interests are reflected in the financial statements.
	The financial statements of PPL, PPL Energy Supply, 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 14 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 except PPL Energy Supply)
	PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Rates are generally established based on a historical or future test period adjusted to exclude unusual or nonrecurring items. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
Accounting Records	'
	Accounting Records (All Registrants except PPL Energy Supply)
	The system of accounts for domestic regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions.
Use of Estimates	'
	Use of Estimates
	The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Loss Accruals	'
	Loss Accruals
	Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of the uncertain future events and (2) the amount of the loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other events. Loss accruals for environmental remediation are discounted when appropriate.
	The accrual of contingencies that might result in gains is not recorded, unless realization is assured.
Changes in Classification	'
	Changes in Classification
	The classification of certain amounts in the 2012 and 2011 financial statements have been changed to conform to the current presentation. The changes in classification 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 except PPL Electric)
	Energy and energy-related contracts are used to hedge the variability of expected cash flows associated with the generating units and marketing activities, as well as for trading purposes at PPL Energy Supply. Interest rate contracts are used to hedge exposures to changes in the fair value of debt instruments and to hedge exposures to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Foreign currency exchange contracts are used to hedge foreign currency exposures, primarily associated with PPL's investments in U.K. subsidiaries. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation.
	Certain energy and energy-related contracts meet the definition of a derivative, while others do 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 energy contracts have been excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. All other contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. These contracts are recorded as "Price risk management assets" and "Price risk management liabilities" on the Balance Sheets. 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." PPL considers intra-month transactions to be spot activity, which is not accounted for as a derivative.
	Energy and energy-related contracts are assigned a strategy and accounting classification. Processes exist that allow for subsequent review and validation of the contract information. See Note 19 for more information. The accounting department provides the traders and the risk management department with guidelines on appropriate accounting classifications for various contract types and strategies. Some examples of these guidelines include, but are not limited to:
	       Physical coal, limestone, lime, uranium, electric transmission, gas transportation, gas storage and renewable energy credit contracts not traded on an exchange are not derivatives due to the lack of net settlement provisions.
	       Only contracts where physical delivery is deemed probable throughout the entire term of the contract can qualify for NPNS.
	       Physical transactions that permit cash settlement and financial transactions do not qualify for NPNS because physical delivery cannot be asserted; however, these transactions can receive cash flow hedge treatment if they effectively hedge the volatility in the future cash flows for energy-related commodities.
	       Certain purchased option contracts or net purchased option collars may receive cash flow hedge treatment.
	       Derivative transactions that do not qualify for NPNS or cash flow hedge treatment, or for which NPNS or cash flow hedge treatment is not elected, are recorded at fair value through earnings.
	A similar process is also followed by the treasury department as it relates to interest rate and foreign currency derivatives. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to:
	       Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring.
	       Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges.
	       Transactions entered into to hedge fluctuations in the fair value of existing debt can be designated 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 treatment are marked to fair value through earnings. These transactions generally include foreign currency swaps 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 included in customer rates.
	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 Energy Supply reflects its net realized and unrealized gains and losses associated with all derivatives that are held for trading purposes in "Unregulated wholesale energy" on the Statements of Income.
	See Notes 18 and 19 for additional information on derivatives.
	(PPL and PPL Electric)
	To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. See Notes 18 and 19 for additional information.
Revenue Recognition	'
	Revenue Recognition
	(All Registrants)
	Operating revenues, except for certain energy and energy-related contracts that meet the definition of derivative instruments and "Energy-related businesses," are 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 being read at the end of the month. Unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh by the estimated average cents per kWh. Unbilled wholesale energy revenues are recorded at month-end to reflect estimated amounts until actual dollars and MWhs are confirmed and invoiced. Any difference between estimated and actual revenues is adjusted the following month.
	Certain PPL subsidiaries participate primarily in the PJM RTO, as well as in other RTOs and ISOs. In PJM, PPL EnergyPlus is a marketer, a load-serving entity and a seller for PPL Energy Supply's generation subsidiaries. A function of interchange accounting is to match participants' MWh entitlements (generation plus scheduled bilateral purchases) against their MWh obligations (load plus scheduled bilateral sales) during every hour of every day. If the net result during any given hour is an entitlement, the participant is credited with a spot-market sale to the RTO at the respective market price for that hour; if the net result is an obligation, the participant is charged with a spot-market purchase at the respective market price for that hour. PPL Energy Supply records the hourly net sales in its Statements of Income as "Unregulated wholesale energy" if in a net sales position and "Energy purchases" if in a net purchase position.
	(PPL)
	WPD's revenue is primarily from charges to suppliers to use its distribution system to deliver electricity to the end-user. WPD's allowed revenue is not dependent on volume delivered over each price control period. 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 given period. Under recoveries are recovered and recorded in the next regulatory year. Over-recoveries are reflected in the current period as a liability and are not included in revenue.
	(PPL and PPL Energy Supply)
	PPL Energy Supply records non-derivative energy marketing activity in the period when the energy is delivered. Generally, sales contracts held for non-trading purposes are reported gross on the Statements of Income within "Unregulated wholesale energy" and "Unregulated retail energy." However, non-trading physical sales and purchases of electricity at major market delivery points (which is any delivery point with liquid pricing available, such as the pricing hub for PJM West), are netted and reported in the Statements of Income within "Unregulated wholesale energy" or "Energy purchases," depending on the net hourly position. Certain energy and energy-related contracts that meet the definition of derivative instruments are recorded at fair value with subsequent changes in fair value recognized as revenue or expense (see Note 19), unless hedge accounting is applied or NPNS is elected. If derivatives meet cash flow hedging criteria, changes in fair value are recorded in AOCI. The unrealized and realized results of derivative and non-derivative contracts that are designated as proprietary trading activities are reported net on the Statements of Income within "Unregulated wholesale energy."
	"Energy-related businesses" revenue primarily includes revenue from PPL Energy Supply's mechanical contracting and engineering subsidiaries. These subsidiaries record revenue from construction contracts on the percentage-of-completion method of accounting, measured by the actual cost incurred to date as a percentage of the estimated total cost for each contract. Accordingly, costs and estimated earnings in excess of billings on uncompleted contracts are recorded within "Unbilled revenues" on the Balance Sheets, and billings in excess of costs and estimated earnings on uncompleted contracts are recorded within "Other current liabilities" on the Balance Sheets. The amount of costs and estimated earnings in excess of billings was $14 million and $12 million at December 31, 2013 and 2012, and the amount of billings in excess of costs and estimated earnings was $75 million and $70 million at December 31, 2013 and 2012.
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. See Note 10 for information related to the acquisition of WPD Midlands.
	(PPL, PPL Energy Supply and PPL Electric)
	In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative suppliers (including PPL EnergyPlus) at a discount, which reflects a provision for uncollectible accounts. The alternative 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 the purchase price paid and are classified as Level 2 in the fair value hierarchy. During 2013, 2012 and 2011, PPL Electric purchased $985 million, $848 million and $875 million of accounts receivable from unaffiliated third parties. During 2013, 2012 and 2011, PPL Electric purchased $294 million, $313 million and $264 million of accounts receivable from PPL EnergyPlus.
	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 the 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
	(All Registrants)
	Cash Equivalents
	All highly liquid investments with original maturities of three months or less are considered to be cash equivalents.
	Restricted Cash and Cash Equivalents
	Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. 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 shown as "Restricted cash and cash equivalents" for PPL and PPL Energy Supply and included in "Other current assets" for PPL Electric, LKE, LG&E and KU while the noncurrent portion is included in "Other noncurrent assets" for all Registrants.
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 securities including investments in the NDT funds and defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk.
	The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows:
	       Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.
	       Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability.
	       Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value.
	Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy.
Investments	'
	Investments
	(All Registrants)
	Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term.
	Short-term Investments
	Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets.
	Investments in Debt and Equity Securities
	Investments in debt securities are classified as held-to-maturity and measured at amortized cost when there is an intent and ability to hold the securities to maturity. Debt and equity securities held principally to capitalize on fluctuations in their value with the intention of selling them in the near-term are classified as trading. All other investments in debt and equity securities are classified as available-for-sale. Both trading and available-for-sale securities are carried at fair value. The specific identification method is used to calculate realized gains and losses on debt and equity securities. Any unrealized gains and losses on trading securities are included in earnings.
	The criteria for determining whether a decline in fair value of a debt security is other than temporary and whether the other-than-temporary impairment is recognized in earnings or reported in OCI require that when a debt security is in an unrealized loss position and:
	       there is an intent or a requirement to sell the security before recovery, the other-than-temporary impairment is recognized currently in earnings; or
	       there is no intent or requirement to sell the security before recovery, the portion of the other-than-temporary impairment that is considered a credit loss, if any, is recognized currently in earnings and the remainder of the other-than-temporary impairment is reported in OCI, net of tax.
	Unrealized gains and losses on available-for-sale equity securities are reported, net of tax, in OCI. When an equity security's decline in fair value below amortized cost is determined to be an other-than-temporary impairment, the unrealized loss is recognized currently in earnings. See Notes 18 and 23 for additional information on investments in debt and equity securities.
	Equity Method Investment (PPL, LKE and KU)
	Investments in entities over which PPL, LKE and KU have the ability to exercise significant influence, but not control, are accounted for using the equity method of accounting and are reported in “Other Investments” on PPL's Balance Sheet and in “Other noncurrent assets” on LKE's and KU's Balance Sheets. In accordance with the accounting guidance for equity method investments, the recoverability of the investment is periodically assessed. If an identified event or change in circumstances requires an impairment evaluation, the fair value of the investment is assessed. The difference between the carrying amount of the investment and its estimated fair value is recognized as an impairment loss when the loss in value is deemed other-than-temporary and such loss is included in “Other-Than-Temporary Impairments” on the Statements of Income.
	KU owns 20% of the common stock of EEI, which is accounted for as an equity method investment. During 2012, KU recorded losses of $8 million from its share of EEI's operating results. In December 2012, KU concluded that an other-than-temporary decline in the value of its investment in EEI had occurred. KU recorded an impairment charge of $25 million ($15 million, after-tax) which reduced the investment balance to zero, the estimated fair value at December 31, 2013 and 2012. See Note 18 for additional information.
	Cost Method Investment (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 LKE, LG&E and KU Balance Sheets and in “Other investments” on the PPL Balance Sheets. LG&E and KU and ten other electric utilities are equity owners of OVEC. OVEC's power is currently supplied to LG&E and KU and 11 other companies affiliated with the various owners. LG&E and KU own 5.63% and 2.5% of OVEC's common stock. Pursuant to a power purchase agreement, LG&E and KU are contractually entitled to their ownership percentage of OVEC's output, which is approximately 120 MW for LG&E and approximately 53 MW for KU.
	LG&E's and KU's combined investment in OVEC is not significant. The direct exposure to loss as a result of LG&E's and KU's involvement with OVEC is generally limited to the value of their investments; however, LG&E and KU may be 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 regulatory liability, both of which are being amortized using the units-of-production method until March 2026, the expiration date of the agreement. See Notes 15 and 20 for additional discussion on 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, such as the Ironwood and WPD Midlands acquisitions, 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 costs 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 cost 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.
	(All Registrants except PPL Energy Supply)
	AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC as a return is provided on construction work in progress.
	(PPL and PPL Energy Supply)
	Nuclear fuel-related costs, including fuel, conversion, enrichment, fabrication and assemblies, are capitalized as PP&E. Such costs are amortized as the fuel is spent using the units-of-production method and included in "Fuel" on the Statements of Income.
	PPL Energy Supply capitalizes interest costs as part of construction costs. Capitalized interest, excluding AFUDC for PPL, is as follows.
	Depreciation
	(All Registrants)
	Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators.
Goodwill and Other Intangible Assets	'
	(All Registrants)
	Goodwill and Other Intangible Assets
	Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination.
	Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets.
	When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider the expected use of the asset; the expected useful life of other assets to which the useful life of the intangible asset may relate; legal, regulatory, or contractual provisions that may limit the useful life; the company's historical experience as evidence of its ability to support renewal or extension; the effects of obsolescence, demand, competition, and other economic factors; and the level of maintenance expenditures required to obtain the expected future cash flows from the asset.
	PPL and PPL Energy Supply account for RECs as intangible assets. PPL and PPL Energy Supply buy and/or sell RECs and also create RECs through owned renewable energy generation facilities. In any period, PPL and PPL Energy Supply can be a net purchaser or seller of RECs depending on their contractual obligations to purchase or deliver RECs and the production of RECs from their renewable energy generation facilities. The carrying value of RECs created from their renewable energy generation facilities is initially recorded at zero value and purchased RECs are initially recorded based on their purchase price. When RECs are consumed to satisfy an obligation to deliver RECs to meet a state's Renewable Portfolio Standard Obligation or when RECs are sold to third parties, they are removed from the Balance Sheet at their weighted-average carrying value. Since the economic benefits of RECs are not diminished until they are consumed, RECs are not amortized; rather, they are expensed when consumed or a gain or loss is recognized when sold. Such expense is included in "Energy purchases" on the Statements of Income. Gains and losses on the sale of RECs are included in "Other operation and maintenance" on the Statements of Income.
	PPL, PPL Energy Supply, LKE, LG&E and KU account for emission allowances as intangible assets. PPL, PPL Energy Supply, LKE, 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. When 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; rather, 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 Statements of Income.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. 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 remaining life of the associated long-lived asset. See Note 21 for additional information on AROs.
Compensation and Benefits	'
	Compensation and Benefits
	Defined Benefits (All Registrants)
	Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets.
	The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value.
	PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the expected average remaining service of active plan participants. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the expected average remaining service period of active plan participants.
	See Note 13 for a discussion of defined benefits.
	Stock-Based Compensation
	(All Registrants except LG&E and KU)
	PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value method. 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 12 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Energy Supply, 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 and valuation allowances on deferred tax assets.
	Significant management judgment is also required to determine the amount of benefit to be recognized in relation to an uncertain tax position. The Registrants use a two-step process to evaluate tax positions. The first step requires an entity to determine whether, based on the technical merits supporting a particular tax position, it is more likely than not (greater than a 50% chance) that the tax position will be sustained. This determination assumes that the relevant taxing authority will examine the tax position and is aware of all the relevant facts surrounding the tax position. The second step requires an entity to recognize in the financial statements the benefit of a tax position that meets the more-likely-than-not recognition criterion. The benefit recognized is measured at the largest amount of benefit that has a likelihood of realization, upon settlement, that exceeds 50%. The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements of the Registrants in future periods.
	Deferred income taxes reflect the net future tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes, as well as the tax effects of net operating losses and tax credit carryforwards.
	The Registrants record valuation allowances to reduce deferred tax assets to the amounts that are more likely than not to be realized. The Registrants consider the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies in initially recording and subsequently reevaluating the need for valuation allowances. If the Registrants determine that they are able to realize deferred tax assets in the future in excess of recorded net deferred tax assets, adjustments to the valuation allowances increase income by reducing tax expense in the period that such determination is made. Likewise, if the Registrants determine that they are not able to realize all or part of net deferred tax assets in the future, adjustments to the valuation allowances would decrease income by increasing tax expense in the period that such determination is made.
	The Registrants defer investment tax credits when the credits are utilized and amortize the deferred amounts over the average lives of the related assets.
	The Registrants recognize interest and penalties in "Income Taxes" on their Statements of Income.
	See Note 5 for additional discussion regarding income taxes.
	(All Registrants except PPL Energy Supply)
	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 would be recorded under GAAP is deferred and included on the Balance Sheet in noncurrent "Regulatory assets" or "Regulatory liabilities."
	(All Registrants except PPL)
	The income tax provision for PPL Energy Supply, 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 Energy Supply, PPL Electric, LKE, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes. At December 31, the following intercompany tax receivables (payables) were recorded.
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	'
	Other
	Leases
	(All Registrants)
	The Registrants evaluate whether arrangements entered into contain leases for accounting purposes. See Note 11 for a discussion of arrangements under which PPL Energy Supply, LG&E and KU are lessees for accounting purposes.
Fuel, Materials and Supplies	'
	Fuel, Materials and Supplies
	(All Registrants)
	Fuel, natural gas stored underground and materials and supplies are valued at the lower of cost or market 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 disclosure. See Note 15 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 of common stock upon acquisition.
Foreign Currency Translation	'
	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 translated at average exchange rates prevailing during the period included in PPL's results of operations. Adjustments resulting from foreign currency translation are recorded in AOCI.
	Gains or losses relating to foreign currency transactions are recognized in "Other Income (Expense) - net" on the Statements of Income. See Note 17 for additional information.
PPL Electric Utilities Corp [Member]	'
Summary Of Significant Accounting Policies [Line Items]	'
Regulation	'
	PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Rates are generally established based on a historical or future test period adjusted to exclude unusual or nonrecurring items. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
Accounting Records	'
	Accounting Records (All Registrants except PPL Energy Supply)
	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.
Treasury Stock	'
	Treasury Stock (PPL and PPL Electric)
	PPL and PPL Electric restore all shares of common stock acquired to authorized but unissued shares of common stock upon acquisition.
LG And E And KU Energy LLC [Member]	'
Summary Of Significant Accounting Policies [Line Items]	'
Regulation	'
	PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Rates are generally established based on a historical or future test period adjusted to exclude unusual or nonrecurring items. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
Accounting Records	'
	Accounting Records (All Registrants except PPL Energy Supply)
	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.
Louisville Gas And Electric Co [Member]	'
Summary Of Significant Accounting Policies [Line Items]	'
Regulation	'
	PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Rates are generally established based on a historical or future test period adjusted to exclude unusual or nonrecurring items. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
Accounting Records	'
	Accounting Records (All Registrants except PPL Energy Supply)
	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.
Kentucky Utilities Co [Member]	'
Summary Of Significant Accounting Policies [Line Items]	'
Regulation	'
	PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Rates are generally established based on a historical or future test period adjusted to exclude unusual or nonrecurring items. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 6 for additional details regarding regulatory matters.
Accounting Records	'
	Accounting Records (All Registrants except PPL Energy Supply)
	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.

Fair_Value_Measurements_and_Cr1

Fair Value Measurements and Credit Concentration (Policies)	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements and Credit Concentration [Abstract]	'
Fair Value Measurements	'
	Transfers between levels are recognized at end-of-reporting-period values.

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Policies)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities [Abstract]	'
Price Risk Management	'
	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Summary Of Significant Accounting Policies [Line Items]	'
Schedule of Utility Revenue	'
	For the years ended December 31, the Statements of Income "Utility" line item contains rate-regulated revenue from the following:
					2013			2012			2011
	Domestic electric and gas revenue (a)			$	4,842		$	4,519		$	4,674
	U.K. electric revenue (b)				2,359			2,289			1,618
		Total		$	7,201		$	6,808		$	6,292
	(a)       Represents revenue from regulated generation, transmission and/or distribution in Pennsylvania, Kentucky, Virginia and Tennessee, including regulated wholesale revenue.
	(b)       Represents electric distribution revenue from the operation of WPD's distribution networks. 2011 includes eight months of revenue for WPD Midlands.
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
	2013		$	64			$	39			$	4	(d)		$	43			$	64
	2012			54				55	(b)							45				64
	2011			55				65	(b)							66	(c)			54
	PPL Energy Supply
	2013		$	23			$	1							$	3			$	21
	2012			15				12	(b)							4				23
	2011			20				14	(b)							19	(c)			15
	PPL Electric
	2013		$	18			$	32							$	32			$	18
	2012			17				32								31				18
	2011			17				33								33				17
	LKE
	2013		$	19			$	4			$	4	(d)		$	5			$	22
	2012			17				9								7				19
	2011			17				15								15				17
	LG&E
	2013		$	1			$	2			$	1	(d)		$	2			$	2
	2012			2				2								3				1
	2011			2				5								5				2
	KU
	2013		$	2			$	3			$	3	(d)		$	4			$	4
	2012			2				4								4				2
	2011			6				6								10				2
	(a)       Primarily related to uncollectible accounts written off.
	(b)       Includes amounts related to the SMGT bankruptcy. See Note 15 for additional information.
	(c)       Includes amounts related to the June 2011, FERC approved settlement agreement between PPL and the California ISO related to the sales made to the California ISO during the period October 2000 through June 2001 that were not paid to PPL subsidiaries. Therefore, the receivable and the related allowance for doubtful accounts were reversed and the settlement recorded.
	(d)       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 Energy Supply						PPL Electric					LKE				LG&E
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Margin deposits posted to
		counterparties				$	67		$	43		$	67		$	43
	Cash collateral posted to
		counterparties					22			32													$	22	$	32	$	22	$	32
	Low carbon network fund (a)						27			14
	Funds deposited with a trustee (b)						12			13								$	12		$	13
	Ironwood debt service reserves						17			17			17			17
	Other						11			16			1			3
			Total			$	156		$	135		$	85		$	63		$	12		$	13	$	22	$	32	$	22	$	32
	(a)       Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
	(b)       Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
Capitalized Interest Costs	'
	Capitalized interest, excluding AFUDC for PPL, is as follows.
						PPL
			PPL			Energy Supply
	2013		$	46		$	37
	2012			53			47
	2011			51			47
Weighted-average Rates of Depreciation	'
	Following are the weighted-average rates of depreciation at December 31.
			2013
						PPL
						Energy			PPL
			PPL			Supply			Electric			LKE				LG&E			KU
	Regulated utility plant			2.94						2.61				4.07			4.52			3.77
	Non-regulated PP&E - Generation			3.1			3.1
			2012
						PPL
						Energy			PPL
			PPL			Supply			Electric			LKE				LG&E			KU
	Regulated utility plant			3.12						2.57				4.39			4.91			4.06
	Non-regulated PP&E - Generation			3.05			3.05
Schedule of Utility Inventory	'
	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31.
						PPL						PPL Energy Supply						LKE					LG&E				KU
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Fuel					$	305		$	284		$	163		$	135		$	141		$	149	$	64	$	61	$	77	$	88
	Natural gas stored underground (a)						49			50			2			8			48			42		48		42
	Materials and supplies						348			339			193			184			89			85		42		39		47		46
						$	702		$	673		$	358		$	327		$	278		$	276	$	154	$	142	$	124	$	134
	(a)       The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.
PPL Energy Supply LLC [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 Energy Supply						PPL Electric					LKE				LG&E
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Margin deposits posted to
		counterparties				$	67		$	43		$	67		$	43
	Cash collateral posted to
		counterparties					22			32													$	22	$	32	$	22	$	32
	Low carbon network fund (a)						27			14
	Funds deposited with a trustee (b)						12			13								$	12		$	13
	Ironwood debt service reserves						17			17			17			17
	Other						11			16			1			3
			Total			$	156		$	135		$	85		$	63		$	12		$	13	$	22	$	32	$	22	$	32
	(a)       Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
	(b)       Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
Capitalized Interest Costs	'
	PPL Energy Supply capitalizes interest costs as part of construction costs. Capitalized interest, excluding AFUDC for PPL, is as follows.
						PPL
			PPL			Energy Supply
	2013		$	46		$	37
	2012			53			47
	2011			51			47
Intercompany tax receivables (payables)	'
	At December 31, the following intercompany tax receivables (payables) were recorded.
			2013			2012
	PPL Energy Supply		$	44		$	-38
	PPL Electric			-19			22
	LKE			-28			-12
	LG&E			-8			5
	KU			-27			-15
Schedule of Utility Inventory	'
	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31.
						PPL						PPL Energy Supply						LKE					LG&E				KU
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Fuel					$	305		$	284		$	163		$	135		$	141		$	149	$	64	$	61	$	77	$	88
	Natural gas stored underground (a)						49			50			2			8			48			42		48		42
	Materials and supplies						348			339			193			184			89			85		42		39		47		46
						$	702		$	673		$	358		$	327		$	278		$	276	$	154	$	142	$	124	$	134
	(a)       The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.
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 Energy Supply						PPL Electric					LKE				LG&E
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Margin deposits posted to
		counterparties				$	67		$	43		$	67		$	43
	Cash collateral posted to
		counterparties					22			32													$	22	$	32	$	22	$	32
	Low carbon network fund (a)						27			14
	Funds deposited with a trustee (b)						12			13								$	12		$	13
	Ironwood debt service reserves						17			17			17			17
	Other						11			16			1			3
			Total			$	156		$	135		$	85		$	63		$	12		$	13	$	22	$	32	$	22	$	32
	(a)       Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
	(b)       Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
Intercompany tax receivables (payables)	'
	At December 31, the following intercompany tax receivables (payables) were recorded.
			2013			2012
	PPL Energy Supply		$	44		$	-38
	PPL Electric			-19			22
	LKE			-28			-12
	LG&E			-8			5
	KU			-27			-15
LG And E And KU Energy LLC [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 Energy Supply						PPL Electric					LKE				LG&E
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Margin deposits posted to
		counterparties				$	67		$	43		$	67		$	43
	Cash collateral posted to
		counterparties					22			32													$	22	$	32	$	22	$	32
	Low carbon network fund (a)						27			14
	Funds deposited with a trustee (b)						12			13								$	12		$	13
	Ironwood debt service reserves						17			17			17			17
	Other						11			16			1			3
			Total			$	156		$	135		$	85		$	63		$	12		$	13	$	22	$	32	$	22	$	32
	(a)       Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
	(b)       Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
Intercompany tax receivables (payables)	'
	At December 31, the following intercompany tax receivables (payables) were recorded.
			2013			2012
	PPL Energy Supply		$	44		$	-38
	PPL Electric			-19			22
	LKE			-28			-12
	LG&E			-8			5
	KU			-27			-15
Schedule of Utility Inventory	'
	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31.
						PPL						PPL Energy Supply						LKE					LG&E				KU
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Fuel					$	305		$	284		$	163		$	135		$	141		$	149	$	64	$	61	$	77	$	88
	Natural gas stored underground (a)						49			50			2			8			48			42		48		42
	Materials and supplies						348			339			193			184			89			85		42		39		47		46
						$	702		$	673		$	358		$	327		$	278		$	276	$	154	$	142	$	124	$	134
	(a)       The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.
Louisville Gas And Electric Co [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 Energy Supply						PPL Electric					LKE				LG&E
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Margin deposits posted to
		counterparties				$	67		$	43		$	67		$	43
	Cash collateral posted to
		counterparties					22			32													$	22	$	32	$	22	$	32
	Low carbon network fund (a)						27			14
	Funds deposited with a trustee (b)						12			13								$	12		$	13
	Ironwood debt service reserves						17			17			17			17
	Other						11			16			1			3
			Total			$	156		$	135		$	85		$	63		$	12		$	13	$	22	$	32	$	22	$	32
	(a)       Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
	(b)       Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
Intercompany tax receivables (payables)	'
	At December 31, the following intercompany tax receivables (payables) were recorded.
			2013			2012
	PPL Energy Supply		$	44		$	-38
	PPL Electric			-19			22
	LKE			-28			-12
	LG&E			-8			5
	KU			-27			-15
Schedule of Utility Inventory	'
	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31.
						PPL						PPL Energy Supply						LKE					LG&E				KU
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Fuel					$	305		$	284		$	163		$	135		$	141		$	149	$	64	$	61	$	77	$	88
	Natural gas stored underground (a)						49			50			2			8			48			42		48		42
	Materials and supplies						348			339			193			184			89			85		42		39		47		46
						$	702		$	673		$	358		$	327		$	278		$	276	$	154	$	142	$	124	$	134
	(a)       The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.
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.
			2013			2012
	PPL Energy Supply		$	44		$	-38
	PPL Electric			-19			22
	LKE			-28			-12
	LG&E			-8			5
	KU			-27			-15
Schedule of Utility Inventory	'
	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31.
						PPL						PPL Energy Supply						LKE					LG&E				KU
						2013			2012			2013			2012			2013			2012		2013		2012		2013		2012
	Fuel					$	305		$	284		$	163		$	135		$	141		$	149	$	64	$	61	$	77	$	88
	Natural gas stored underground (a)						49			50			2			8			48			42		48		42
	Materials and supplies						348			339			193			184			89			85		42		39		47		46
						$	702		$	673		$	358		$	327		$	278		$	276	$	154	$	142	$	124	$	134
	(a)       The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.

Segment_and_Related_Informatio1

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment and Related Information [Abstract]	'
Segment and Related Information	'
	Financial data for the segments are:
	Income Statement Data						2013			2012			2011
	Revenues from external customers by product
			U.K. Regulated
				Utility service (a)			$	2,359		$	2,289		$	1,618
				Energy-related businesses				44			47			35
					Total			2,403			2,336			1,653
			Kentucky Regulated
				Utility service (a)				2,976			2,759			2,793
			Pennsylvania Regulated
				Utility service (a)				1,866			1,760			1,881
			Supply
				Energy (b)				4,075			4,970			5,938
				Energy-related businesses				527			461			472
					Total			4,602			5,431			6,410
			Corporate and Other					13
	Total							11,860			12,286			12,737
	Intersegment electric revenues
			Pennsylvania Regulated					4			3			11
			Supply (c)					51			79			26
	Depreciation
			U.K. Regulated					300			279			218
			Kentucky Regulated					334			346			334
			Pennsylvania Regulated					178			160			146
			Supply					318			289			245
			Corporate and Other					31			26			17
	Total							1,161			1,100			960
	Amortization (d)
			U.K. Regulated					19			15			83
			Kentucky Regulated					22			27			27
			Pennsylvania Regulated					19			18			7
			Supply					156			126			137
			Corporate and Other					6
	Total							222			186			254
	Unrealized (gains) losses on derivatives and other hedging activities (b)
			U.K. Regulated					44			52			-8
			Kentucky Regulated					12			11			9
			Supply					180			-36			-315
	Total							236			27			-314
	Interest Expense
			U.K. Regulated					425			421			391
			Kentucky Regulated					212			219			217
			Pennsylvania Regulated					108			99			98
			Supply					228			222			192
			Corporate and Other					33
	Total							1,006			961			898
	Income from Continuing Operations Before Income Taxes
			U.K. Regulated					993			953			358
			Kentucky Regulated					484			263			349
			Pennsylvania Regulated					317			204			257
			Supply (b) (g)					-428			662			1,237
			Corporate and Other					-57
	Total							1,309			2,082			2,201
	Income Taxes (e)
			U.K. Regulated					71			150			33
			Kentucky Regulated					179			80			127
			Pennsylvania Regulated					108			68			68
			Supply					-157			247			463
			Corporate and Other					-21
	Total							180			545			691
	Deferred income taxes and investment tax credits (f)
			U.K. Regulated					-45			26			-39
			Kentucky Regulated					254			136			218
		Pennsylvania Regulated					127			114			106
		Supply					-296			150			299
		Corporate and Other					32
Total							72			426			584
Net Income Attributable to PPL Shareowners
		U.K. Regulated					922			803			325
		Kentucky Regulated					307			177			221
		Pennsylvania Regulated					209			132			173
		Supply (b) (g)					-272			414			776
		Corporate and Other					-36
	Total					$	1,130		$	1,526		$	1,495
Cash Flow Data							2013			2012			2011
Expenditures for long-lived assets
		U.K. Regulated				$	1,280		$	1,016		$	862
		Kentucky Regulated					1,434			768			465
		Pennsylvania Regulated					942			633			490
		Supply					568			736			739
		Corporate and Other					59
Total						$	4,283		$	3,153		$	2,556
			As of December 31,
			2013			2012
Balance Sheet Data
Total Assets
	U.K. Regulated		$	15,895		$	14,073
	Kentucky Regulated			12,016			10,670
	Pennsylvania Regulated			6,846			6,023
	Supply			11,408			12,868
	Corporate and Other (h)			94
Total			$	46,259		$	43,634
(a)       See Note 1 for additional information on Utility Revenue.
(b)       Includes unrealized gains and losses from economic activity. See Note 19 for additional information.
(c)       See "PLR Contracts/Purchase of Accounts Receivable" in Note 16 for a discussion of the basis of accounting between reportable segments.
(d)       Represents non-cash expense items that include amortization of nuclear fuel, regulatory assets, debt discounts and premiums, debt issuance costs, emission allowances and RECs.
(e)       Represents both current and deferred income taxes, including investment tax credits.
(f)       Represents a non-cash expense item that is also included in "Income Taxes."
(g)       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.
(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:
					2013			2012			2011
	Geographic Data
	Revenues from external customers
			U.K.		$	2,403		$	2,336		$	1,653
			U.S.			9,457			9,950			11,084
	Total				$	11,860		$	12,286		$	12,737
Long-lived Assets	'
	Financial data for the segments are:
				As of December 31,
				2013			2012
	Long-Lived Assets
		U.K.		$	11,145		$	9,951
		U.S.			22,638			20,776
	Total			$	33,783		$	30,727

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Basic and Diluted EPS Computations	'
	Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31 used in the EPS calculation are:
					2013		2012		2011
	Income (Numerator)
	Income from continuing operations after income taxes attributable to PPL shareowners				$	1,128	$	1,532	$	1,493
	Less amounts allocated to participating securities					6		8		6
	Less issuance costs on subsidiary's preferred securities redeemed							6
	Income from continuing operations after income taxes available to PPL common
		shareowners - Basic				1,122		1,518		1,487
	Plus interest charges (net of tax) related to Equity Units (a)					44
	Income from continuing operations after income taxes available to PPL common
		shareowners - Diluted			$	1,166	$	1,518	$	1,487
	Income (loss) from discontinued operations (net of income taxes) available to PPL
		common shareowners - Basic and Diluted			$	2	$	-6	$	2
	Net income attributable to PPL shareowners				$	1,130	$	1,526	$	1,495
	Less amounts allocated to participating securities					6		8		6
	Less issuance costs on subsidiary's preferred securities redeemed							6
	Net income available to PPL common shareowners - Basic					1,124		1,512		1,489
	Plus interest charges (net of tax) related to Equity Units					44
	Net income available to PPL common shareowners - Diluted				$	1,168	$	1,512	$	1,489
	Shares of Common Stock (Denominator)
	Weighted-average shares - Basic EPS					608,983		580,276		550,395
	Add incremental non-participating securities:
			Share-based payment awards (b)			1,062		563		400
			Equity Units (a)			52,568
			Forward sale agreements and purchase contracts (b)			460		787		157
	Weighted-average shares - Diluted EPS					663,073		581,626		550,952
	Basic EPS
	Available to PPL common shareowners:
			Income from continuing operations after income taxes		$	1.85	$	2.62	$	2.7
			Income (loss) from discontinued operations (net of income taxes)					-0.01		0.01
			Net Income		$	1.85	$	2.61	$	2.71
	Diluted EPS
	Available to PPL common shareowners:
			Income from continuing operations after income taxes		$	1.76	$	2.61	$	2.7
			Income (loss) from discontinued operations (net of income taxes)					-0.01
			Net Income		$	1.76	$	2.6	$	2.7
	(a)       In 2013, the If-Converted Method was applied to the Equity Units prior to settlement.
	(b)       The Treasury Stock Method was applied to non-participating share-based payment awards, forward sale agreements and the 2010 Purchase Contracts for 2012 and 2011.
Common Stock Issuances	'
	For the year ended December 31, PPL issued common stock related to stock-based compensation plans, ESOP and DRIP as follows:
	(Shares in thousands)		2013
	Stock-based compensation plans (a)			1,552
	ESOP			275
	DRIP			549
	(a)       Includes stock options exercised, 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 were excluded from the computations of diluted EPS because the effect would have been antidilutive.
	(Shares in thousands)		2013		2012		2011
	Stock options			4,446		5,293		5,084
	Performance units			55		58		2
	Restricted stock units			29

Income_and_Other_Taxes_Tables

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income and Other Taxes [Line Items]	'
Components of Income (Loss) From Continuing Operations Before Income Taxes	'
	"Income from Continuing Operations Before Income Taxes" included the following.
				2013			2012			2011
	Domestic income			$	196		$	994		$	1,715
	Foreign income				1,113			1,088			486
		Total		$	1,309		$	2,082		$	2,201
Components of Deferred Tax Assets and Liabilities	'
	Significant components of PPL's deferred income tax assets and liabilities were as follows:
					2013			2012
	Deferred Tax Assets
		Deferred investment tax credits			$	137		$	130
		Regulatory obligations				144			124
		Accrued pension costs				140			276
		Federal loss carryforwards				331			524
		State loss carryforwards				304			305
		Federal and state tax credit carryforwards				332			287
		Foreign capital loss carryforwards				467			525
		Foreign loss carryforwards				6			6
		Foreign - pensions				202			254
		Foreign - regulatory obligations				26			27
		Foreign - other				12			16
		Contributions in aid of construction				137			134
		Domestic - other				211			239
		Valuation allowances				-663			-706
			Total deferred tax assets			1,786			2,141
	Deferred Tax Liabilities
		Domestic plant - net				4,073			3,967
		Taxes recoverable through future rates				151			141
		Unrealized gain on qualifying derivatives				37			122
		Other regulatory assets				244			319
		Reacquired debt costs				34			40
		Foreign plant - net				859			937
		Domestic - other				78			66
			Total deferred tax liabilities			5,476			5,592
	Net deferred tax liability				$	3,690		$	3,451
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	'
	At December 31, PPL had the following loss and tax credit carryforwards.
				2013				Expiration
	Loss carryforwards
		Federal net operating losses (a)		$	952			2028-2032
		State net operating losses (a) (b)			5,011			2014-2033
		State capital losses (c)			125			2014-2016
		Foreign net operating losses (d)			30			Indefinite
		Foreign capital losses (e)			2,333			Indefinite
	Credit carryforwards
		Federal investment tax credit			245			2025-2033
		Federal alternative minimum tax credit			32			Indefinite
		Federal foreign tax credit			17			2017-2023
		Federal - other			35			2016-2033
		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 $185 million has been recorded against the deferred tax assets for these losses.
	(c)       A valuation allowance of $5 million has been recorded against the deferred tax assets for these losses.
	(d)       A valuation allowance of $6 million has been recorded against the deferred tax assets for these losses.
	(e)       A valuation allowance of $467 million has been recorded against the deferred tax assets for these losses.
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
	2013		$	706		$	29						$	72	(a)	$	663
	2012			724			18		$	10				46	(a)		706
	2011			464			190			112	(b)			42	(a)		724
	(a)       The reductions of the U.K. statutory income tax rate in 2013, 2012 and 2011 resulted in $67 million, $46 million and $35 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 of 2013, 2012 and 2011.
	(b)       Primarily related to a $101 million valuation allowance that was recorded against certain deferred tax assets as a result of the 2011 acquisition of WPD Midlands. See Note 10 for additional information on the acquisition.
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 as follows:
						2013			2012			2011
	Income Tax Expense (Benefit)
		Current - Federal				$	-75					$	54
		Current - State					1		$	-2			-20
		Current - Foreign					181			121			73
				Total Current Expense (Benefit)			107			119			107
		Deferred - Federal					73			553			558
		Deferred - State					45			103			127
		Deferred - Foreign					-53			35			-23
				Total Deferred Expense (Benefit), excluding operating loss carryforwards			65			691			662
		Investment tax credit, net - Federal					-10			-10			-10
		Tax expense (benefit) of operating loss carryforwards
			Deferred - Federal (a)				36			-195			-30
			Deferred - State				-18			-60			-38
				Total Tax Expense (Benefit) of Operating Loss Carryforwards			18			-255			-68
		Total income taxes from continuing operations				$	180		$	545		$	691
		Total income tax expense - Federal				$	24		$	348		$	572
		Total income tax expense (benefit) - State					28			41			69
		Total income tax expense - Foreign					128			156			50
				Total income taxes from continuing operations		$	180		$	545		$	691
	In the table above, the following income tax expense (benefits) are excluded from income taxes from continuing operations.
	(a)       A 2012 Federal income tax return adjustment was recorded in 2013 related to a reduction in the 2012 NOL recorded in the filed return. The reduction was primarily due to PPL's decision, at the time of filing, to utilize regular modified accelerated cost recovery system (MACRS) depreciation rates for certain non-regulated assets otherwise eligible for bonus tax depreciation.
					2013			2012			2011
	Discontinued operations				$	1		$	-4		$	2
	Stock-based compensation recorded to Additional Paid-in Capital					-2			-1			3
	Issuance costs of Purchase Contracts recorded to Additional Paid-in Capital											-9
	Valuation allowance on state deferred taxes related to issuance costs of Purchase Contracts
		recorded to Additional Paid-in Capital				-2						4
	Other comprehensive income					159			-526			-144
	Valuation allowance on state deferred taxes recorded to other comprehensive income					-7						7
			Total		$	149		$	-531		$	-137
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 as follows:
						2013			2012			2011
	Reconciliation of Income Tax Expense
		Federal income tax on Income from Continuing Operations Before Income Taxes at
			statutory tax rate - 35%			$	458		$	729		$	770
	Increase (decrease) due to:
		State income taxes, net of federal income tax benefit					-7			27			63
		State valuation allowance adjustments (a)					24			13			36
		Impact of lower U.K. income tax rates (b)					-129			-110			-33
		U.S. income tax on foreign earnings - net of foreign tax credit (c)					9			26			-26
		Federal and state tax reserves adjustments (d)					-43			-1			39
		Foreign tax reserves adjustments (e)					-2			-5			-141
		Federal and state income tax return adjustments (a) (f)					-5			16			-17
		Foreign income tax return adjustments					-4			-6
		Impact of the U.K. Finance Acts on deferred tax balances (b)					-97			-75			-69
		Federal income tax credits (g)					-9			-12			-13
		Depreciation not normalized (a)					-8			-11			-20
		Foreign valuation allowance adjustments (e)											147
		State deferred tax rate change (h)					15			-19			-26
		Net operating loss carryforward adjustments (i)								-9
		Intercompany interest on U.K. financing entities (j)					-10			-9			-8
		Other					-12			-9			-11
				Total increase (decrease)			-278			-184			-79
	Total income taxes from continuing operations					$	180		$	545		$	691
	Effective income tax rate						13.80%			26.20%			31.40%
	(a)       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.
	During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. Due to the decrease in projected taxable income related to bonus depreciation and a decrease in projected future taxable income, PPL recorded $43 million in state deferred income tax expense related to deferred tax valuation allowances during 2011.
	Additionally, the 100% Pennsylvania bonus depreciation deduction created a current state income tax benefit for the flow-through impact of Pennsylvania regulated state tax depreciation. The federal provision for 100% bonus depreciation generally applies to property placed into service before January 1, 2012. The placed in-service deadline was extended to January 1, 2013 for property that had a cost in excess of $1 million, had a production period longer than one year and had a tax life of at least ten years. PPL's tax deduction for 100% bonus regulated tax depreciation was zero in 2013 and was significantly lower in 2012 than in 2011.
	(b)       The U.K. Finance Act 2013, enacted 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 related to both rate decreases.
	The U.K. Finance Act 2012, enacted in July 2012, reduced the U.K. statutory income tax rate from 25% to 24% retroactive to April 1, 2012 and from 24% to 23% effective April 1, 2013. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2012 related to both rate decreases.
	The U.K. Finance Act 2011, enacted in July 2011, reduced the U.K. statutory income tax rate from 27% to 26% retroactive to April 1, 2011 and from 26% to 25% effective April 1, 2012. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2011 related to both rate decreases.
	(c)       During 2013, PPL recorded $25 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 reflected on an amended 2010 U.S. tax return.
	During 2012, PPL recorded a $23 million adjustment to federal income tax expense related to the recalculation of 2010 U.K. earnings and profits.
	During 2011, PPL recorded a $28 million federal income tax benefit related to U.K. pension contributions.
	(d)       In 1997, the U.K. imposed a Windfall Profits Tax (WPT) on privatized utilities, including WPD. PPL filed its federal income tax returns for years subsequent to its 1997 and 1998 claims for refund on the basis that the U.K. WPT was creditable. In September 2010, the U.S. Tax Court (Tax Court) ruled in PPL's favor in a dispute with the IRS, concluding that the U.K. WPT is a creditable tax for U.S. tax purposes. As a result, and with the finalization of other issues, PPL recorded a $42 million tax benefit in 2010. In January 2011, the IRS appealed the Tax Court's decision to the U.S. Court of Appeals for the Third Circuit (Third Circuit). In December 2011, the Third Circuit issued its opinion reversing the Tax Court's decision, holding that the U.K. WPT is not a creditable tax. As a result of the Third Circuit's adverse determination, PPL recorded a $39 million expense in 2011. In June 2012, the U.S. Court of Appeals for the Fifth Circuit issued a contrary opinion in an identical case involving another company. In July 2012, PPL filed a petition for a writ of certiorari seeking U.S. Supreme Court review of the Third Circuit's opinion. The Supreme Court granted PPL's petition and oral argument was held in February 2013. On May 20, 2013, the Supreme Court reversed the Third Circuit's opinion and ruled that the WPT is a creditable tax. As a result of the Supreme Court ruling, PPL recorded a tax benefit of $44 million during 2013, of which $19 million relates to interest.
	PPL recorded a tax benefit of $7 million during 2013 and $6 million during 2012 and 2011 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization is zero.
	(e)       During 2012, PPL recorded a foreign tax benefit following resolution of a U.K. tax issue related to interest expense.
	During 2011, WPD reached an agreement with HMRC related to the amount of the capital losses that resulted from prior years' restructuring in the U.K. and recorded a $147 million foreign tax benefit for the reversal of tax reserves related to the capital losses. Additionally, WPD recorded a $147 million valuation allowance for the amount of capital losses that, more likely than not, will not be utilized.
	(f)       During 2012, PPL recorded $16 million in federal and state income tax expense related to the filing of the 2011 federal and state income tax returns. Of this amount, $5 million relates to the reversal of prior years' state income tax benefits related to regulated depreciation. PPL changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year. In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates for network assets. The IRS guidance provided a safe harbor method of determining whether the repair expenditures for electric transmission and distribution property can be currently deducted for tax purposes. PPL adopted the safe harbor method with the filing of its 2011 federal income tax return.
	During 2011, PPL recorded $17 million in federal and state tax benefits related to the filing of the 2010 federal and state income tax returns. Of this amount, $7 million in tax benefits related to an additional domestic manufacturing deduction resulting from revised bonus depreciation amounts and $3 million in tax benefits related to the flow-through impact of Pennsylvania regulated state tax depreciation.
	(g)       During 2013, 2012 and 2011, PPL recorded a deferred tax benefit related to investment tax credits on progress expenditures related to hydroelectric plant expansions. See Note 8 for additional information.
	(h)       During 2013, 2012 and 2011, 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.
	(i)       During 2012, PPL recorded adjustments to deferred taxes related to net operating loss carryforwards of LKE based on income tax return adjustments.
	(j)       During 2013, 2012 and 2011, PPL recorded income tax benefits related to interest expense on intercompany loans.
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 as follows:
					2013			2012			2011
	Taxes, other than income
		State gross receipts			$	135		$	135		$	140
		State utility realty				2			2			-9
		State capital stock				2			7			18
		Foreign property				147			147			113
		Domestic property and other				78			75			64
		Total			$	364		$	366		$	326
Unrecognized Tax Benefits	'
	Changes to unrecognized tax benefits were as follows:
				2013			2012
	PPL
		Beginning of period		$	92		$	145
		Additions based on tax positions of prior years			3			15
		Reductions based on tax positions of prior years			-32			-61
		Additions based on tax positions related to the current year						7
		Reductions based on tax positions related to the current year						-3
		Settlements			-30			-2
		Lapse of applicable statute of limitation			-11			-9
		End of period		$	22		$	92
	PPL Energy Supply
		Beginning of period		$	30		$	28
		Additions based on tax positions of prior years						4
		Reductions based on tax positions of prior years			-15			-2
		End of period		$	15		$	30
	PPL Electric
		Beginning of period		$	26		$	73
		Reductions based on tax positions of prior years			-17			-43
		Additions based on tax positions related to the current year						5
		Lapse of applicable statute of limitation			-9			-9
		End of period		$			$	26
	At December 31, 2013, it was reasonably possible that during the next 12 months the total amount of unrecognized tax benefits could increase or decrease by the following amounts.
			Increase			Decrease
	PPL		$			$	22
	PPL Energy Supply						15
	At December 31, the total unrecognized tax benefits and related indirect effects that, if recognized, would decrease the effective tax rate were as follows.
			2013			2012
	PPL		$	21		$	38
	PPL Energy Supply			14			13
	PPL Electric						3
	At December 31, the following receivable (payable) balances were recorded for interest related to tax positions.
			2013			2012
	PPL		$	15		$	-16
	PPL Energy Supply			15			17
	PPL Electric			3			1
	The following interest expense (benefit) was recognized in income taxes.
			2013			2012			2011
	PPL		$	-30		$	-4		$	27
	PPL Energy Supply			5			-4			6
	PPL Electric			-7			-4			-5
Summary of Income Tax Examinations	'
	With few exceptions, at December 31, 2013, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows:
					PPL
			PPL		Energy Supply		PPL Electric		LKE		LG&E		KU
	U.S. (federal) (a)		1997 and prior		1997 and prior		1997 and prior		10/31/2010 and prior		10/31/2010 and prior		10/31/2010 and prior
	Pennsylvania (state)		2009 and prior		2009 and prior		2008 and prior
	Kentucky (state)		2008 and prior						2010 and prior		2010 and prior		2010 and prior
	Montana (state)		2009 and prior		2009 and prior
	U.K. (foreign)		2011 and prior
	(a)        For LKE, LG&E, and KU, the ten month period ending October 31, 2010 remains open under the standard three year statute of limitations; however, the IRS has completed its audit of these periods under the Compliance Assurance Process, effectively closing them to audit adjustments. No issues remain outstanding.
PPL Energy Supply LLC [Member]	'
Income and Other Taxes [Line Items]	'
Components of Deferred Tax Assets and Liabilities	'
	Significant components of PPL Energy Supply's deferred income tax assets and liabilities were as follows:
					2013			2012
	Deferred Tax Assets
		Deferred investment tax credits			$	84		$	75
		Accrued pension costs				39			94
		Federal loss carryforwards				28			51
		Federal tax credit carryforwards				131			113
		State loss carryforwards				80			79
		Other				69			68
		Valuation allowances				-78			-74
			Total deferred tax assets			353			406
	Deferred Tax Liabilities
		Plant - net				1,392			1,579
		Unrealized gain on qualifying derivatives				38			173
		Other				46			44
			Total deferred tax liabilities			1,476			1,796
	Net deferred tax liability				$	1,123		$	1,390
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	'
	At December 31, PPL Energy Supply had the following loss and tax credit carryforwards.
				2013				Expiration
	Loss carryforwards
		Federal net operating losses		$	80			2031-2032
		State net operating losses (a)			1,204			2014-2033
	Credit carryforwards
		Federal investment tax credit			120			2031-2033
		Federal - other			9			2031-2033
	(a) A valuation allowance of $78 million has been recorded against the deferred tax assets for these losses.
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	'
	The changes in deferred tax valuation allowances were:
						Additions
			Balance at						Charged to							Balance
			Beginning			Charged			Other							at End
			of Period			to Income			Accounts				Deductions			of Period
	2013		$	74		$	4									$	78
	2012			72			2										74
	2011			408			22						$	358	(a)		72
	(a)       During 2011, PPL Energy Supply distributed its membership interest in PPL Global to PPL Energy Funding. See Note 9 for additional information.
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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows:
						2013			2012			2011
	Income Tax Expense (Benefit)
		Current - Federal				$	134		$	89		$	139
		Current - State					21			22			-12
				Total Current Expense (Benefit)			155			111			127
		Deferred - Federal					-287			193			251
		Deferred - State					-27			10			70
				Total Deferred Expense (Benefit), excluding operating loss carryforwards			-314			203			321
		Investment tax credit, net - federal					-5			-2			-3
		Tax expense (benefit) of operating loss carryforwards
			Deferred - Federal (a)				22			-48
			Deferred - State							-1
				Total Tax Expense (Benefit) of Operating Loss Carryforwards			22			-49
		Total income taxes from continuing operations (b)				$	-142		$	263		$	445
		Total income tax expense - Federal				$	-136		$	232		$	387
		Total income tax expense (benefit) - State					-6			31			58
				Total income taxes from continuing operations (b)		$	-142		$	263		$	445
	(a)        A 2012 federal income tax return adjustment was recorded in 2013 related to a reduction in the 2012 NOL recorded in the filed return. The reduction was primarily due to PPL's decision, at the time of filing, to utilize regular MACRS depreciation rates for certain non-regulated assets otherwise eligible for bonus tax depreciation.
	(b)       Excludes current and deferred federal, state and foreign tax expense (benefit) recorded to Discontinued Operations of $3 million in 2011. Also, excludes federal, state and foreign tax expense (benefit) recorded to OCI of $47 million in 2013, $(267) million in 2012 and $(83) million in 2011. The deferred tax benefit of operating loss carryforwards was insignificant for 2011.
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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows:
						2013			2012			2011
	Reconciliation of Income Tax Expense
		Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at
			statutory tax rate - 35%			$	-130		$	258		$	424
	Increase (decrease) due to:
		State income taxes, net of federal income tax benefit					-22			33			60
		State valuation allowance adjustments (a)					4			2			22
		State deferred tax rate change (b)					15			-19			-26
		Federal and state tax reserves adjustments (c)					6			-2			2
		Federal and state income tax return adjustments (d)					-1			4			-22
		Federal income tax credits (e)					-8			-12			-12
		Other					-6			-1			-3
				Total increase (decrease)			-12			5			21
	Total income taxes from continuing operations					$	-142		$	263		$	445
	Effective income tax rate						38.30%			35.60%			36.70%
	(a)       During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. Due to the decrease in projected taxable income related to bonus depreciation and a decrease in projected future taxable income, PPL Energy Supply recorded state deferred income tax expense related to deferred tax valuation allowances during 2011.
	(b)       During 2013, 2012 and 2011, PPL Energy Supply 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. .
	(c)       During 2013, PPL Energy Supply reversed $3 million in tax benefits related to a 2008 change in method of accounting for certain expenditures for tax purposes and recorded $4 million in federal tax expense related to differences in over (under) payment interest rates applied to audit claims as a result of the U.S. Supreme Court decision related to Windfall Profits Tax.
	(d)       During 2011, PPL Energy Supply recorded federal and state tax benefits related to the filing of the 2010 federal and state income tax returns. Of this amount, $7 million in tax benefits related to an additional domestic manufacturing deduction resulting from revised bonus depreciation amounts.
	(e)       During 2013, 2012 and 2011, PPL Energy Supply recorded a deferred tax benefit related to investment tax credits on progress expenditures related to hydroelectric plant expansions. See Note 8 for additional information.
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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows:
					2013			2012			2011
	Taxes, other than income
		State gross receipts			$	37		$	35		$	31
		State capital stock				1			5			12
		Property and other				28			29			28
			Total		$	66		$	69		$	71
Unrecognized Tax Benefits	'
	Changes to unrecognized tax benefits were as follows:
				2013			2012
	PPL
		Beginning of period		$	92		$	145
		Additions based on tax positions of prior years			3			15
		Reductions based on tax positions of prior years			-32			-61
		Additions based on tax positions related to the current year						7
		Reductions based on tax positions related to the current year						-3
		Settlements			-30			-2
		Lapse of applicable statute of limitation			-11			-9
		End of period		$	22		$	92
	PPL Energy Supply
		Beginning of period		$	30		$	28
		Additions based on tax positions of prior years						4
		Reductions based on tax positions of prior years			-15			-2
		End of period		$	15		$	30
	PPL Electric
		Beginning of period		$	26		$	73
		Reductions based on tax positions of prior years			-17			-43
		Additions based on tax positions related to the current year						5
		Lapse of applicable statute of limitation			-9			-9
		End of period		$			$	26
	At December 31, 2013, it was reasonably possible that during the next 12 months the total amount of unrecognized tax benefits could increase or decrease by the following amounts.
			Increase			Decrease
	PPL		$			$	22
	PPL Energy Supply						15
	At December 31, the total unrecognized tax benefits and related indirect effects that, if recognized, would decrease the effective tax rate were as follows.
			2013			2012
	PPL		$	21		$	38
	PPL Energy Supply			14			13
	PPL Electric						3
	At December 31, the following receivable (payable) balances were recorded for interest related to tax positions.
			2013			2012
	PPL		$	15		$	-16
	PPL Energy Supply			15			17
	PPL Electric			3			1
	The following interest expense (benefit) was recognized in income taxes.
			2013			2012			2011
	PPL		$	-30		$	-4		$	27
	PPL Energy Supply			5			-4			6
	PPL Electric			-7			-4			-5
PPL Electric Utilities Corp [Member]	'
Income and Other 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.
					2013			2012
	Deferred Tax Assets
		Accrued pension costs			$	42		$	81
		Contributions in aid of construction				109			106
		Regulatory obligations				38			24
		State loss carryforwards				35			39
		Federal loss carryforwards				72			81
		Other				45			46
			Total deferred tax assets			341			377
	Deferred Tax Liabilities
		Electric utility plant - net				1,366			1,229
		Taxes recoverable through future rates				129			122
		Reacquired debt costs				23			27
		Other regulatory assets				129			174
		Other				8			12
			Total deferred tax liabilities			1,655			1,564
	Net deferred tax liability				$	1,314		$	1,187
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	'
	At December 31, PPL Electric had the following loss carryforwards.
				2013				Expiration
	Loss carryforwards
		Federal net operating losses		$	206			2031-2032
		State net operating losses			534			2030-2032
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:
						2013			2012			2011
	Income Tax Expense (Benefit)
		Current - Federal				$	-15		$	-28		$	-25
		Current - State					-4			-18			-13
				Total Current Expense (Benefit)			-19			-46			-38
		Deferred - Federal					109			162			123
		Deferred - State					16			42			25
				Total Deferred Expense (Benefit), excluding operating loss carryforwards			125			204			148
		Investment tax credit, net - Federal					-1			-1			-2
		Tax expense (benefit) of operating loss carryforwards
			Deferred - Federal				4			-72			-12
			Deferred - State				-1			-17			-28
				Total Tax Expense (Benefit) of Operating Loss Carryforwards			3			-89			-40
		Total income tax expense				$	108		$	68		$	68
		Total income tax expense - Federal				$	97		$	61		$	84
		Total income tax expense (benefit) - State					11			7			-16
				Total income tax expense		$	108		$	68		$	68
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:
						2013			2012			2011
	Reconciliation of Income Taxes
		Federal income tax on Income Before Income Taxes at statutory tax rate - 35%				$	111		$	71		$	90
	Increase (decrease) due to:
		State income taxes, net of federal income tax benefit					16			9			12
		Amortization of investment tax credit					-1			-1			-2
		Federal and state tax reserves adjustments (a)					-9			-8			-9
		Federal and state income tax return adjustments (b)					-1			7			-4
		Depreciation not normalized (c)					-6			-8			-17
		Other					-2			-2			-2
				Total increase (decrease)			-3			-3			-22
	Total income tax expense					$	108		$	68		$	68
	Effective income tax rate						34.10%			33.30%			26.50%
	(a)       PPL Electric recorded a tax benefit of $7 million during 2013 and $6 million during 2012 and 2011 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization is zero.
	(b)       PPL Electric changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year. In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates for network assets. The IRS guidance provided a safe harbor method of determining whether the repair expenditures for electric transmission and distribution property can be currently deducted for tax purposes. PPL Electric adopted the safe harbor method with the filing of its 2011 federal income tax return and recorded a $5 million adjustment to federal and state income tax expense resulting from the reversal of prior years' state income tax benefits related to regulated depreciation.
	During 2011, PPL Electric recorded a $5 million federal and state income tax benefit as a result of filing its 2010 federal and state income tax returns. Of this amount, $3 million in tax benefits related to the flow-through impact of Pennsylvania regulated 100% bonus tax depreciation.
	(c)       During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. The 100% Pennsylvania bonus depreciation deduction created a current state income tax benefit for the flow-through impact of Pennsylvania regulated state tax depreciation. The federal provision for 100% bonus depreciation generally applies to property placed into service before January 1, 2012. The placed in service deadline was extended to January 1, 2013 for property that had a cost in excess of $1 million, had a production period longer that one year and had a tax life of at least ten years. PPL Electric's tax deduction for 100% bonus depreciation was zero in 2013 and was significantly lower in 2012 than in 2011.
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:
					2013			2012			2011
	Taxes, other than income
		State gross receipts			$	98		$	101		$	109
		State utility realty (a)				2			2			-10
		State capital stock				1			1			4
		Property and other				2			1			1
			Total		$	103		$	105		$	104
	(a)       2011 includes PURTA tax that was refunded to PPL Electric customers in 2011.
Unrecognized Tax Benefits	'
	Changes to unrecognized tax benefits were as follows:
				2013			2012
	PPL
		Beginning of period		$	92		$	145
		Additions based on tax positions of prior years			3			15
		Reductions based on tax positions of prior years			-32			-61
		Additions based on tax positions related to the current year						7
		Reductions based on tax positions related to the current year						-3
		Settlements			-30			-2
		Lapse of applicable statute of limitation			-11			-9
		End of period		$	22		$	92
	PPL Energy Supply
		Beginning of period		$	30		$	28
		Additions based on tax positions of prior years						4
		Reductions based on tax positions of prior years			-15			-2
		End of period		$	15		$	30
	PPL Electric
		Beginning of period		$	26		$	73
		Reductions based on tax positions of prior years			-17			-43
		Additions based on tax positions related to the current year						5
		Lapse of applicable statute of limitation			-9			-9
		End of period		$			$	26
	At December 31, 2013, it was reasonably possible that during the next 12 months the total amount of unrecognized tax benefits could increase or decrease by the following amounts.
			Increase			Decrease
	PPL		$			$	22
	PPL Energy Supply						15
	At December 31, the total unrecognized tax benefits and related indirect effects that, if recognized, would decrease the effective tax rate were as follows.
			2013			2012
	PPL		$	21		$	38
	PPL Energy Supply			14			13
	PPL Electric						3
	At December 31, the following receivable (payable) balances were recorded for interest related to tax positions.
			2013			2012
	PPL		$	15		$	-16
	PPL Energy Supply			15			17
	PPL Electric			3			1
	The following interest expense (benefit) was recognized in income taxes.
			2013			2012			2011
	PPL		$	-30		$	-4		$	27
	PPL Energy Supply			5			-4			6
	PPL Electric			-7			-4			-5
LG And E And KU Energy LLC [Member]	'
Income and Other Taxes [Line Items]	'
Components of Deferred Tax Assets and Liabilities	'
	Significant components of LKE's deferred income tax assets and liabilities were as follows:
					2013			2012
	Deferred Tax Assets
		Net operating loss carryforward			$	222		$	376
		Tax credit carryforwards				179			170
		Regulatory liabilities				107			99
		Accrued pension costs				26			42
		Capital loss carryforward				4			5
		Income taxes due to customers				23			26
		Deferred investment tax credits				52			54
		Other				57			41
		Valuation allowances				-4			-5
			Total deferred tax assets			666			808
	Deferred Tax Liabilities
		Plant - net				1,327			1,171
		Regulatory assets				133			152
		Other				12			13
			Total deferred tax liabilities			1,472			1,336
	Net deferred tax liability				$	806		$	528
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	'
	At December 31, LKE had the following loss and tax credit carryforwards.
				2013			Expiration
	Loss carryforwards
		Federal net operating losses		$	523		2028-2032
		State net operating losses			1,024		2028-2032
		State capital losses			106		2014-2016
	Credit carryforwards
		Federal investment tax credit			125		2025-2028
		Federal alternative minimum tax credit			28		Indefinite
		Federal - other			26		2016-2033
		State - other			9		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
	2013		$	5					$	1	(a)		$	4
	2012			5										5
	2011			6						1	(a)			5
	(a)       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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were:
					2013			2012			2011
	Income Tax Expense (Benefit)
		Current - Federal			$	-59		$	-32		$	-71
		Current - State				10			2			6
				Total Current Expense (Benefit)		-49			-30			-65
		Deferred - Federal				244			185			208
		Deferred - State				20			15			16
				Total Deferred Expense, excluding benefits of operating loss carryforwards		264			200			224
		Investment tax credit, net - Federal				-4			-6			-6
		Tax benefit of operating loss carryforwards
			Deferred - Federal			-4			-46
			Deferred - State			-1			-12
				Total Tax Benefit of Operating Loss Carryforwards		-5			-58
		Total income tax expense from continuing operations (a)			$	206		$	106		$	153
		Total income tax expense - Federal			$	177		$	101		$	131
		Total income tax expense - State				29			5			22
				Total income tax expense from continuing operations (a)	$	206		$	106		$	153
	(a)       Excludes current and deferred federal and state tax expense (benefit) recorded to Discontinued Operations of $1 million in 2013, $(4) million in 2012, and $(1) million in 2011. Also, excludes deferred federal and state tax expense (benefit) recorded to OCI of $18 million in 2013, $(12) million in 2012 and $(1) million in 2011.
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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were:
						2013			2012			2011
	Reconciliation of Income Taxes
		Federal income tax on Income Before Income Taxes at
			statutory tax rate - 35%			$	193		$	116		$	147
	Increase (decrease) due to:
		State income taxes, net of federal income tax benefit					20			6			15
		Amortization of investment tax credit					-4			-6			-5
		Net operating loss carryforward (a)								-9
		Other					-3			-1			-4
				Total increase (decrease)			13			-10			6
	Total income tax expense from continuing operations					$	206		$	106		$	153
	Effective income tax rate						37.40%			32.00%			36.50%
	(a)       During 2012, LKE recorded adjustments to deferred taxes related to net operating loss carryforwards based on income tax return adjustments.
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 (Loss) from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were:
						2013			2012			2011
	Taxes, other than income
		Property and other				$	48		$	46		$	37
				Total		$	48		$	46		$	37
Louisville Gas And Electric Co [Member]	'
Income and Other 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:
					2013			2012
	Deferred Tax Assets
		Regulatory liabilities			$	59		$	54
		Deferred investment tax credits				15			16
		Income taxes due to customers				19			21
		Other				28			9
			Total deferred tax assets			121			100
	Deferred Tax Liabilities
		Plant - net				585			526
		Regulatory assets				83			86
		Accrued pension costs				24			27
		Other				8			9
			Total deferred tax liabilities			700			648
	Net deferred tax liability				$	579		$	548
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:
						2013			2012			2011
	Income Tax Expense (Benefit)
		Current - Federal				$	52		$	-2		$	12
		Current - State					16			3			8
				Total Current Expense (Benefit)			68			1			20
		Deferred - Federal					33			65			52
		Deferred - State					-2			6			2
				Total Deferred Expense, excluding benefits of operating loss carryforwards			31			71			54
		Investment tax credit, net - Federal					-2			-3			-3
		Tax benefit of operating loss carryforwards
			Deferred - Federal				-3
				Total Tax Benefit of Operating Loss Carryforwards			-3
		Total income tax expense				$	94		$	69		$	71
		Total income tax expense - Federal				$	80		$	60		$	61
		Total income tax expense - State					14			9			10
				Total income tax expense		$	94		$	69		$	71
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:
						2013			2012			2011
	Reconciliation of Income Taxes
		Federal income tax on Income Before Income Taxes at
			statutory tax rate - 35%			$	90		$	67		$	68
	Increase (decrease) due to:
		State income taxes, net of federal income tax benefit					10			5			7
		Amortization of investment tax credit					-2			-3			-3
		Other					-4						-1
				Total increase (decrease)			4			2			3
	Total income tax expense					$	94		$	69		$	71
	Effective income tax rate						36.60%			35.90%			36.40%
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:
						2013			2012			2011
	Taxes, other than income
		Property and other				$	24		$	23		$	18
				Total		$	24		$	23		$	18
Kentucky Utilities Co [Member]	'
Income and Other Taxes [Line Items]	'
Components of Deferred Tax Assets and Liabilities	'
	Significant components of KU's deferred income tax assets and liabilities were as follows:
					2013			2012
	Deferred Tax Assets
		Regulatory liabilities			$	47		$	45
		Deferred investment tax credits				38			38
		Net operating loss carryforward				23			20
		Income taxes due to customers				4			5
		Accrued pension costs							-5
		Other				8			7
			Total deferred tax assets			120			110
	Deferred Tax Liabilities
		Plant - net				721			623
		Regulatory assets				50			65
		Other				4			5
			Total deferred tax liabilities			775			693
	Net deferred tax liability				$	655		$	583
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:
						2013			2012			2011
	Income Tax Expense (Benefit)
		Current - Federal				$	51		$	-20		$	-8
		Current - State					12			-1			4
				Total Current Expense (Benefit)			63			-21			-4
		Deferred - Federal					66			111			101
		Deferred - State					8			11			10
				Total Deferred Expense, excluding benefits of operating loss carryforwards			74			122			111
		Investment tax credit, net - Federal					-2			-3			-3
		Tax benefit of operating loss carryforwards
			Deferred - Federal				-3			-20
				Total Tax Benefit of Operating Loss Carryforwards			-3			-20
		Total income tax expense (a)				$	132		$	78		$	104
		Total income tax expense - Federal				$	112		$	68		$	90
		Total income tax expense - State					20			10			14
				Total income tax expense (a)		$	132		$	78		$	104
	(a)       Excludes deferred federal and state tax (benefit) recorded to OCI of less than $1 million in 2013 and $1 million in 2012.
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:
						2013			2012			2011
	Reconciliation of Income Taxes
		Federal income tax on Income Before Income Taxes at
			statutory tax rate - 35%			$	126		$	75		$	99
	Increase (decrease) due to:
		State income taxes, net of federal income tax benefit					14			6			9
		Amortization of investment tax credit					-2			-3			-3
		Other					-6						-1
				Total increase (decrease)			6			3			5
	Total income tax expense					$	132		$	78		$	104
	Effective income tax rate						36.70%			36.30%			36.90%
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:
						2013			2012			2011
	Taxes, other than income
		Property and other				$	24		$	23		$	19
				Total		$	24		$	23		$	19

Utility_Rate_Regulation_Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2013
Utility Rate Regulation [Line Items]	'
Regulatory Assets and Liabilities	'
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
		Demand side management			8			1			3			1			5
	Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
		Storm costs			94			109			51			59			43			50
		Unamortized loss on debt			28			31			18			20			10			11
		Interest rate swaps			44			67			44			67
		AROs			44			26			21			15			23			11
		Other			12			29			5			7			7			22
	Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
	Current Regulatory Liabilities:
			Environmental cost recovery					$	4											$	4
			Gas supply clause		$	3			4		$	3		$	4
			Fuel adjustment clause			4			1								$	4			1
			Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition of LKE by PPL.
PPL Electric Utilities Corp [Member]	'
Utility Rate Regulation [Line Items]	'
Regulatory Assets and Liabilities	'
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
		Demand side management			8			1			3			1			5
	Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
		Storm costs			94			109			51			59			43			50
		Unamortized loss on debt			28			31			18			20			10			11
		Interest rate swaps			44			67			44			67
		AROs			44			26			21			15			23			11
		Other			12			29			5			7			7			22
	Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
	Current Regulatory Liabilities:
			Environmental cost recovery					$	4											$	4
			Gas supply clause		$	3			4		$	3		$	4
			Fuel adjustment clause			4			1								$	4			1
			Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
LG And E And KU Energy LLC [Member]	'
Utility Rate Regulation [Line Items]	'
Regulatory Assets and Liabilities	'
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
		Demand side management			8			1			3			1			5
	Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
		Storm costs			94			109			51			59			43			50
		Unamortized loss on debt			28			31			18			20			10			11
		Interest rate swaps			44			67			44			67
		AROs			44			26			21			15			23			11
		Other			12			29			5			7			7			22
	Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
	Current Regulatory Liabilities:
			Environmental cost recovery					$	4											$	4
			Gas supply clause		$	3			4		$	3		$	4
			Fuel adjustment clause			4			1								$	4			1
			Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition of LKE by PPL.
Louisville Gas And Electric Co [Member]	'
Utility Rate Regulation [Line Items]	'
Regulatory Assets and Liabilities	'
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
		Demand side management			8			1			3			1			5
	Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
		Storm costs			94			109			51			59			43			50
		Unamortized loss on debt			28			31			18			20			10			11
		Interest rate swaps			44			67			44			67
		AROs			44			26			21			15			23			11
		Other			12			29			5			7			7			22
	Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
	Current Regulatory Liabilities:
			Environmental cost recovery					$	4											$	4
			Gas supply clause		$	3			4		$	3		$	4
			Fuel adjustment clause			4			1								$	4			1
			Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition of LKE by PPL.
Kentucky Utilities Co [Member]	'
Utility Rate Regulation [Line Items]	'
Regulatory Assets and Liabilities	'
	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.
				PPL						PPL Electric
				2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1
		Gas supply clause			10			11
		Fuel adjustment clause			2			6
		Demand side management			8			1
		Other			6					$	6
	Total current regulatory assets			$	33		$	19		$	6
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	509		$	730		$	257		$	362
		Taxes recoverable through future rates			306			293			306			293
		Storm costs			147			168			53			59
		Unamortized loss on debt			85			96			57			65
		Interest rate swaps			44			67
		Accumulated cost of removal of utility plant			98			71			98			71
		AROs			44			26
		Other			13			32			1			3
	Total noncurrent regulatory assets			$	1,246		$	1,483		$	772		$	853
	Current Regulatory Liabilities:
		Generation supply charge		$	23		$	27		$	23		$	27
		Environmental cost recovery						4
		Gas supply clause			3			4
		Transmission service charge			8			6			8			6
		Transmission formula rate			20						20
		Fuel adjustment clause			4			1
		Universal Service Rider			10			17			10			17
		Storm damage expense			14						14
		Gas line tracker			6
		Other			2			2			1			2
	Total current regulatory liabilities			$	90		$	61		$	76		$	52
	Noncurrent Regulatory Liabilities:
		Accumulated cost of removal of utility plant		$	688		$	679
		Coal contracts (a)			98			141
		Power purchase agreement - OVEC (a)			100			108
		Net deferred tax assets			30			34
		Act 129 compliance rider			15			8		$	15		$	8
		Defined benefit plans			26			17
		Interest rate swaps			86			14
		Other			5			9
	Total noncurrent regulatory liabilities			$	1,048		$	1,010		$	15		$	8
				LKE						LG&E						KU
				2013			2012			2013			2012			2013			2012
	Current Regulatory Assets:
		Environmental cost recovery		$	7		$	1		$	2		$	1		$	5
		Gas supply clause			10			11			10			11
		Fuel adjustment clause			2			6			2			6
		Demand side management			8			1			3			1			5
	Total current regulatory assets			$	27		$	19		$	17		$	19		$	10
	Noncurrent Regulatory Assets:
		Defined benefit plans		$	252		$	368		$	164		$	232		$	88		$	136
		Storm costs			94			109			51			59			43			50
		Unamortized loss on debt			28			31			18			20			10			11
		Interest rate swaps			44			67			44			67
		AROs			44			26			21			15			23			11
		Other			12			29			5			7			7			22
	Total noncurrent regulatory assets			$	474		$	630		$	303		$	400		$	171		$	230
	Current Regulatory Liabilities:
			Environmental cost recovery					$	4											$	4
			Gas supply clause		$	3			4		$	3		$	4
			Fuel adjustment clause			4			1								$	4			1
			Gas line tracker			6						6
		Other			1												1
Total current regulatory liabilities				$	14		$	9		$	9		$	4		$	5		$	5
Noncurrent Regulatory Liabilities:
	Accumulated cost of removal
		of utility plant		$	688		$	679		$	299		$	297		$	389		$	382
	Coal contracts (a)				98			141			43			61			55			80
	Power purchase agreement - OVEC (a)				100			108			69			75			31			33
	Net deferred tax assets				30			34			26			28			4			6
	Defined benefit plans				26			17									26			17
	Interest rate swaps				86			14			43			7			43			7
	Other				5			9			2			3			3			6
Total noncurrent regulatory liabilities				$	1,033		$	1,002		$	482		$	471		$	551		$	531
(a)       These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition of LKE by PPL.

Financing_Activities_Tables

Financing Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Financing Activities [Line Items]	'
Credit Facilities in Place at Period End	'
	The following credit facilities were in place at:
								December 31, 2013														December 31, 2012
																	Letters of							Letters of
																	Credit Issued							Credit Issued
																	and							and
																	Commercial							Commercial
								Expiration									Paper			Unused				Paper
								Date			Capacity			Borrowed			Backup			Capacity		Borrowed		Backup
	PPL
	U.K.
		PPL WW Syndicated
			Credit Facility (a) (d)						Dec. 2016		£	210		£	103					£	107	£	106
		WPD (South West)
			Syndicated Credit Facility (a) (d)						Jan. 2017			245									245
		WPD (East Midlands)
			Syndicated Credit Facility (a) (b) (d)						Apr. 2016			300									300
		WPD (West Midlands)
			Syndicated Credit Facility (a) (b) (d)						Apr. 2016			300									300
		Uncommitted Credit Facilities										84					£	5			79			£	4
				Total U.K. Credit Facilities (c)							£	1,139		£	103		£	5		£	1,031	£	106	£	4
	U.S.
		PPL Capital Funding
			Syndicated Credit Facility (d) (e) (g)						Nov. 2018		$	300		$	270					$	30
	PPL Energy Supply
		Syndicated Credit Facility (d) (e)							Nov. 2017		$	3,000					$	29		$	2,971			$	499
		Letter of Credit Facility (e)							Mar. 2014			150						138			12				132
		Uncommitted Credit Facilities (e)										175						77			98				40
				Total PPL Energy Supply Credit Facilities							$	3,325					$	244		$	3,081			$	671
	PPL Electric
		Syndicated Credit Facility (d) (e)							Oct. 2017		$	300					$	21		$	279			$	1
	LKE
		Syndicated Credit Facility (d) (e) (g)							Oct. 2018		$	75		$	75
	LG&E
		Syndicated Credit Facility (d) (e)							Nov. 2017		$	500					$	20		$	480			$	55
	KU
		Syndicated Credit Facility (d) (e)							Nov. 2017		$	400					$	150		$	250			$	70
		Letter of Credit Facility (d) (e) (f)							May-16			198						198							198
				Total KU Credit Facilities							$	598					$	348		$	250			$	268
	(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)       Under these facilities, WPD (East Midlands) and WPD (West Midlands) each have the ability to request the lenders to issue up to £80 million of letters of credit in lieu of borrowing.
	(c)       PPL WW's amounts borrowed at December 31, 2013 and 2012 were USD-denominated borrowings of $166 million and $171 million, which equated to £103 million and £106 million at the time of the borrowings and bore interest at 1.87% and 0.85%. At December 31, 2013, the unused capacity of WPD's credit facilities was approximately $1.7 billion.
	(d)       Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin.
	(e)       The facilities contain a financial covenant requiring debt to total capitalization not to exceed 65% for PPL Energy Supply and 70% for PPL, 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 credit facilities and subject to certain conditions, PPL Energy Supply may request that its facility's capacity be increased by up to $500 million, PPL Electric and KU each may request up to a $100 million increase in its facility's capacity and LKE may request up to a $25 million increase in its facility's capacity.
	(f)       KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted to loans rather than requiring immediate payment.
	(g)       PPL Capital Funding's and LKE's borrowings at December 31, 2013 bore interest at 1.79% and 1.67%, respectively.
Long-term Debt	'
	Long-term Debt (All Registrants)
					Weighted-Average				December 31,
					Rate		Maturities		2013			2012
	PPL
	U.S.
		Senior Unsecured Notes (a)			4.31%		2014 - 2043		$	5,568		$	4,506
		Senior Secured Notes/First Mortgage Bonds (b) (c) (d) (e)			3.80%		2015 - 2043			5,823			5,587
		Junior Subordinated Notes			5.29%		2019 - 2073			1,908			2,608
		Other			6.95%		2014 - 2020			15			15
				Total U.S. Long-term Debt						13,314			12,716
	U.K.
		Senior Unsecured Notes (f)			5.53%		2016 - 2040			6,872			6,111
		Index-linked Senior Unsecured Notes (g)			1.83%		2043 - 2056			749			608
				Total U.K. Long-term Debt (h)						7,621			6,719
				Total Long-term Debt Before Adjustments						20,935			19,435
		Fair market value adjustments								23			78
		Unamortized premium and (discount), net								-51			-37
				Total Long-term Debt						20,907			19,476
		Less current portion of Long-term Debt								315			751
				Total Long-term Debt, noncurrent					$	20,592		$	18,725
	PPL Energy Supply
		Senior Unsecured Notes (a)			5.32%		2014 - 2038		$	2,493		$	2,581
		Senior Secured Notes (b)			8.86%		2025			49			663
		Other			6.00%		2020			5			5
				Total Long-term Debt Before Adjustments						2,547			3,249
		Fair market value adjustments								-22			22
		Unamortized premium and (discount), net											1
				Total Long-term Debt						2,525			3,272
		Less current portion of Long-term Debt								304			751
				Total Long-term Debt, noncurrent					$	2,221		$	2,521
	PPL Electric
		Senior Secured Notes/First Mortgage Bonds (c) (d)			4.63%		2015 - 2043		$	2,314		$	1,964
		Other			7.38%		2014			10			10
				Total Long-term Debt Before Adjustments						2,324			1,974
		Unamortized discount								-9			-7
				Total Long-term Debt						2,315			1,967
		Less current portion of Long-term Debt								10
				Total Long-term Debt, noncurrent					$	2,305		$	1,967
	LKE
		Senior Unsecured Notes			3.31%		2015 - 2021		$	1,125		$	1,125
		Senior Secured Notes/First Mortgage Bonds (c) (e)			3.18%		2015 - 2043			3,460			2,960
				Total Long-term Debt Before Adjustments						4,585			4,085
		Fair market value adjustments								-1			7
		Unamortized discount								-19			-17
				Total Long-term Debt					$	4,565		$	4,075
	LG&E
		Senior Secured Notes/First Mortgage Bonds (c) (e)			2.77%		2015 - 2043		$	1,359		$	1,109
				Total Long-term Debt Before Adjustments						1,359			1,109
		Fair market value adjustments								-1			6
		Unamortized discount								-5			-3
				Total Long-term Debt					$	1,353		$	1,112
	KU
		Senior Secured Notes/First Mortgage Bonds (c) (e)			3.44%		2015 - 2043		$	2,101		$	1,851
				Total Long-term Debt Before Adjustments						2,101			1,851
		Fair market value adjustments								1			1
		Unamortized discount								-11			-10
				Total Long-term Debt					$	2,091		$	1,842
	(a)       Includes $300 million of 5.70% REset Put Securities due 2035 (REPS). The REPS bear interest at a rate of 5.70% per annum to, but excluding, October 15, 2015 (Remarketing Date). The REPS are required to be put by existing holders on the Remarketing Date either for (a) purchase and remarketing by a designated remarketing dealer or (b) repurchase by PPL Energy Supply. If the remarketing dealer elects to purchase the REPS for remarketing, it will purchase the REPS at 100% of the principal amount, and the REPS will bear interest on and after the Remarketing Date at a new fixed rate per annum determined in the remarketing. PPL Energy Supply has the right to terminate the remarketing process. If the remarketing is terminated at the option of PPL Energy Supply or under certain other circumstances, including the occurrence of an event of default by PPL Energy Supply under the related indenture or a failed remarketing for certain specified reasons, PPL Energy Supply will be required to pay the remarketing dealer a settlement amount as calculated in accordance with the related remarketing agreement.
	(b)       2012 includes lease financing consolidated through a VIE which was repaid in 2013. See Note 22 for additional information.
	(c)       Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $5.1 billion and $4.3 billion at December 31, 2013 and 2012.
	Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $3.2 billion and $2.7 billion at December 31, 2013 and December 31, 2012.
	Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $5.1 billion and $4.4 billion at December 31, 2013 and December 31, 2012.
	(d)       Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (c) above. This amount includes $224 million that may be redeemed 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.
(e)       Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amount, 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 (c) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate.
At December 31, 2013, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $321 million for LKE, comprised of $294 million and $27 million for LG&E and KU. At December 31, 2013, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $604 million for LKE, comprised of $280 million and $324 million for LG&E and KU.
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 process. 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 variable rate tax-exempt revenue bonds totaling $348 million at December 31, 2013 ($120 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.
(f)       Includes £225 million ($368 million at December 31, 2013) of notes that may be redeemed, in total but not in part, on December 21, 2026, at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. Government bond.
(g)       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 principal amounts from 2012 to 2013 was an increase of approximately £12 million ($20 million) resulting from inflation. In addition, this amount includes £225 million ($368 million at December 31, 2013) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026, at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nominated U.K. government bond.
(h)       Includes £3.8 billion ($6.2 billion at December 31, 2013) of notes that may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the notes are withdrawn by any of the rating agencies (Moody's, S&P or Fitch) or reduced to a non-investment grade rating of Ba1 or BB+ in connection with a restructuring event which includes the loss of, or a material adverse change to, the distribution licenses under which the issuer operates.
Long-term Debt Maturities	'
	The aggregate maturities of long-term debt for the periods 2014 through 2018 and thereafter are as follows.
						PPL
						Energy			PPL
			PPL			Supply			Electric			LKE			LG&E			KU
	2014		$	314		$	304		$	10
	2015			1,304			304			100		$	900		$	250		$	250
	2016			814			354
	2017			104			4
	2018			653			403
	Thereafter			17,746			1,178			2,214			3,685			1,109			1,851
	Total		$	20,935		$	2,547		$	2,324		$	4,585		$	1,359		$	2,101
PPL Energy Supply LLC [Member]	'
Financing Activities [Line Items]	'
Commercial paper	'
	The following commercial paper programs were in place at:
								December 31, 2013												December 31, 2012
								Weighted -						Commercial						Weighted -		Commercial
								Average						Paper			Unused			Average		Paper
								Interest Rate			Capacity			Issuances			Capacity			Interest Rate		Issuances
		PPL Energy Supply									$	750					$	750			0.50%	$	356
		PPL Electric							0.23%			300		$	20			280
		LG&E							0.29%			350			20			330			0.42%		55
		KU							0.32%			350			150			200			0.42%		70
				Total							$	1,750		$	190		$	1,560				$	481
Dividends/distributions paid to and capital contributions received from parent/member	'
	(All Registrants except PPL)
	The following distributions and capital contributions occurred in 2013:
					PPL Energy				PPL
					Supply				Electric			LKE				LG&E			KU
	Dividends/distributions paid to parent/member				$	408			$	127		$	254			$	99		$	124
	Capital contributions received from parent/member					1,577				205			243				86			157
PPL Electric Utilities Corp [Member]	'
Financing Activities [Line Items]	'
Commercial paper	'
	The following commercial paper programs were in place at:
								December 31, 2013												December 31, 2012
								Weighted -						Commercial						Weighted -		Commercial
								Average						Paper			Unused			Average		Paper
								Interest Rate			Capacity			Issuances			Capacity			Interest Rate		Issuances
		PPL Energy Supply									$	750					$	750			0.50%	$	356
		PPL Electric							0.23%			300		$	20			280
		LG&E							0.29%			350			20			330			0.42%		55
		KU							0.32%			350			150			200			0.42%		70
				Total							$	1,750		$	190		$	1,560				$	481
Dividends/distributions paid to and capital contributions received from parent/member	'
	(All Registrants except PPL)
	The following distributions and capital contributions occurred in 2013:
					PPL Energy				PPL
					Supply				Electric			LKE				LG&E			KU
	Dividends/distributions paid to parent/member				$	408			$	127		$	254			$	99		$	124
	Capital contributions received from parent/member					1,577				205			243				86			157
LG And E And KU Energy LLC [Member]	'
Financing Activities [Line Items]	'
Dividends/distributions paid to and capital contributions received from parent/member	'
	(All Registrants except PPL)
	The following distributions and capital contributions occurred in 2013:
					PPL Energy				PPL
					Supply				Electric			LKE				LG&E			KU
	Dividends/distributions paid to parent/member				$	408			$	127		$	254			$	99		$	124
	Capital contributions received from parent/member					1,577				205			243				86			157
Louisville Gas And Electric Co [Member]	'
Financing Activities [Line Items]	'
Commercial paper	'
	The following commercial paper programs were in place at:
								December 31, 2013												December 31, 2012
								Weighted -						Commercial						Weighted -		Commercial
								Average						Paper			Unused			Average		Paper
								Interest Rate			Capacity			Issuances			Capacity			Interest Rate		Issuances
		PPL Energy Supply									$	750					$	750			0.50%	$	356
		PPL Electric							0.23%			300		$	20			280
		LG&E							0.29%			350			20			330			0.42%		55
		KU							0.32%			350			150			200			0.42%		70
				Total							$	1,750		$	190		$	1,560				$	481
Dividends/distributions paid to and capital contributions received from parent/member	'
	(All Registrants except PPL)
	The following distributions and capital contributions occurred in 2013:
					PPL Energy				PPL
					Supply				Electric			LKE				LG&E			KU
	Dividends/distributions paid to parent/member				$	408			$	127		$	254			$	99		$	124
	Capital contributions received from parent/member					1,577				205			243				86			157
Kentucky Utilities Co [Member]	'
Financing Activities [Line Items]	'
Commercial paper	'
	The following commercial paper programs were in place at:
								December 31, 2013												December 31, 2012
								Weighted -						Commercial						Weighted -		Commercial
								Average						Paper			Unused			Average		Paper
								Interest Rate			Capacity			Issuances			Capacity			Interest Rate		Issuances
		PPL Energy Supply									$	750					$	750			0.50%	$	356
		PPL Electric							0.23%			300		$	20			280
		LG&E							0.29%			350			20			330			0.42%		55
		KU							0.32%			350			150			200			0.42%		70
				Total							$	1,750		$	190		$	1,560				$	481
Dividends/distributions paid to and capital contributions received from parent/member	'
	(All Registrants except PPL)
	The following distributions and capital contributions occurred in 2013:
					PPL Energy				PPL
					Supply				Electric			LKE				LG&E			KU
	Dividends/distributions paid to parent/member				$	408			$	127		$	254			$	99		$	124
	Capital contributions received from parent/member					1,577				205			243				86			157

Business_Acquisitions_Tables

Business Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013
Business Acquisition [Line Items]	'
Purchase Price and Related Purchase Price Allocation	'
	The fair value of the consideration paid for this acquisition was as follows.
	Aggregate enterprise consideration		$	326
	Less: Fair value of long-term debt outstanding assumed through consolidation (a)			258
	Plus: Restricted cash debt service reserves			17
	Cash consideration paid for equity interests (including working capital adjustments)		$	85
	(a)       The long-term debt assumed through consolidation consisted of $226 million aggregate principal amount of 8.857% senior secured bonds to be fully repaid by December 31, 2025, plus $8 million of debt service reserve loans, and a $24 million fair value adjustment. See Note 7 for information on the February 2013 exchange of a portion of long-term debt assumed through consolidation.
	Purchase Price Allocation
	The following table summarizes the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed through consolidation, and the effective settlement of the tolling agreement through consolidation.
	PP&E		$	505
	Long-term debt (current and noncurrent) (a)			-258
	Tolling agreement (b)			-170
	Other net assets (a)			8
	Net identifiable assets acquired		$	85
	(a)       Represents non-cash activity excluded from the 2012 Statement of Cash Flows.
	(b)       Prior to the acquisition, PPL EnergyPlus had recorded primarily an intangible asset, which represented its rights to and the related accounting for the tolling agreement with PPL Ironwood, LLC. On the acquisition date, PPL Ironwood, LLC recorded a liability, recognized at fair value, for its obligation to PPL EnergyPlus. The tolling agreement assets of PPL EnergyPlus and the tolling agreement liability of PPL Ironwood, LLC eliminate in consolidation for PPL and PPL Energy Supply as a result of the acquisition, and therefore the agreement is considered effectively settled. The difference between the tolling agreement assets and liability resulted in an insignificant loss on the effective settlement of the agreement.
	The fair value of the consideration paid for this acquisition was as follows (in billions).
	Aggregate enterprise consideration		$	6.6
	Less: Fair value of long-term debt outstanding assumed through consolidation			0.8
	Total cash consideration paid			5.8
	Less: Funds used to repay pre-acquisition affiliate indebtedness			1.7
	Cash consideration paid for Central Networks' outstanding ordinary share capital		$	4.1
	The following table summarizes (in billions) the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed.
	Current assets (a)		$	0.2
	PP&E			4.9
	Intangible assets			0.1
	Other noncurrent assets			0.1
	Current liabilities (b)			-0.4
	PPL WEM affiliate indebtedness			-1.7
	Long-term debt (current and noncurrent) (b)			-0.8
	Other noncurrent liabilities (b)			-0.7
	Net identifiable assets acquired			1.7
	Goodwill			2.4
	Net assets acquired		$	4.1
	(a)       Includes gross contractual amount of the accounts receivable acquired of $122 million, which approximates fair value.
	(b)       Represents non-cash activity excluded from the 2011 Statement of Cash Flows.
Separation Benefits	'
	The separation benefits, before income taxes, associated with the reorganization were as follows.
	Severance compensation		$	61
	Early retirement deficiency costs (ERDC) under applicable pension plans			46
	Outplacement services			1
	Total separation benefits		$	108
	The changes in the carrying amounts of accrued severance were as follows.
				2012		2011
	Accrued severance at beginning of period		$	21
	Severance compensation			13	$	48
	Severance paid			-34		-27
	Accrued severance at end of period		$		$	21
Pro-forma Information	'
	WPD Midlands 2011 financial results included in PPL's Statement of Income and included in the U.K. Regulated segment were as follows.
	Operating Revenues				$	790
	Net Income Attributable to PPL Shareowners					137
	Pro forma Information
	The pro forma financial information, which includes WPD Midlands as if the acquisition had occurred January 1, 2010, is as follows.
							2011
	Operating Revenues - PPL consolidated pro forma (unaudited)						$	13,140
	Net Income Attributable to PPL Shareowners - PPL consolidated pro forma (unaudited)							1,800
Nonrecurring Adjustments to Pro-forma Information	'
	The pre-tax nonrecurring credits (expenses) presented in the following table were directly attributable to the acquisition and adjustments were included in the calculation of pro forma operating revenue and net income to remove the effect of these nonrecurring items and the related income tax effects.
				Income Statement
				Line Item					2011
	WPD Midlands acquisition
		2011 Bridge Facility costs (a)		Interest Expense					$	-44
		Foreign currency loss on 2011 Bridge Facility (b)		Other Income (Expense) - net						-57
		Net hedge gains associated with the 2011 Bridge Facility (c)		Other Income (Expense) - net						55
		Hedge ineffectiveness (d)		Interest Expense						-12
		U.K. stamp duty tax (e)		Other Income (Expense) - net						-21
		Separation benefits (f)		Other operation and maintenance						-102
		Other acquisition-related adjustments		(g)						-77
	(a)       The 2011 Bridge Facility costs, primarily commitment and structuring fees, were incurred to establish a bridge facility for purposes of funding the WPD Midlands acquisition purchase price.
	(b)       The 2011 Bridge Facility was denominated in GBP. The amount includes a $42 million foreign currency loss on PPL Capital Funding's repayment of its 2011 Bridge Facility borrowing and a $15 million foreign currency loss associated with proceeds received on the U.S. dollar-denominated senior notes issued by PPL WEM in April 2011 that were used to repay a portion of PPL WEM's borrowing under the 2011 Bridge Facility.
	(c)       The repayment of borrowings on the 2011 Bridge Facility was economically hedged to mitigate the effects of changes in foreign currency exchange rates with forward contracts to purchase GBP, which resulted in net hedge gains.
	(d)       The hedge ineffectiveness includes a combination of ineffectiveness associated with closed out interest rate swaps and a charge recorded as a result of certain interest rate swaps failing hedge effectiveness testing, both associated with the acquisition financing.
	(e)       The U.K. stamp duty tax represents a tax on the transfer of ownership of property in the U.K. incurred in connection with the acquisition.
	(f)       See "Separation Benefits - U.K. Regulated Segment" above.
	(g)       Primarily includes acquisition-related advisory, accounting and legal fees recorded in "Other Income (Expense) - net" and contract termination costs, rebranding costs and relocation costs recorded in "Other operation and maintenance."
PPL Energy Supply LLC [Member]	'
Business Acquisition [Line Items]	'
Purchase Price and Related Purchase Price Allocation	'
	The fair value of the consideration paid for this acquisition was as follows.
	Aggregate enterprise consideration		$	326
	Less: Fair value of long-term debt outstanding assumed through consolidation (a)			258
	Plus: Restricted cash debt service reserves			17
	Cash consideration paid for equity interests (including working capital adjustments)		$	85
	(a)       The long-term debt assumed through consolidation consisted of $226 million aggregate principal amount of 8.857% senior secured bonds to be fully repaid by December 31, 2025, plus $8 million of debt service reserve loans, and a $24 million fair value adjustment. See Note 7 for information on the February 2013 exchange of a portion of long-term debt assumed through consolidation.
	Purchase Price Allocation
	The following table summarizes the allocation of the purchase price to the fair value of the major classes of assets acquired and liabilities assumed through consolidation, and the effective settlement of the tolling agreement through consolidation.
	PP&E		$	505
	Long-term debt (current and noncurrent) (a)			-258
	Tolling agreement (b)			-170
	Other net assets (a)			8
	Net identifiable assets acquired		$	85
	(a)       Represents non-cash activity excluded from the 2012 Statement of Cash Flows.
	(b)       Prior to the acquisition, PPL EnergyPlus had recorded primarily an intangible asset, which represented its rights to and the related accounting for the tolling agreement with PPL Ironwood, LLC. On the acquisition date, PPL Ironwood, LLC recorded a liability, recognized at fair value, for its obligation to PPL EnergyPlus. The tolling agreement assets of PPL EnergyPlus and the tolling agreement liability of PPL Ironwood, LLC eliminate in consolidation for PPL and PPL Energy Supply as a result of the acquisition, and therefore the agreement is considered effectively settled. The difference between the tolling agreement assets and liability resulted in an insignificant loss on the effective settlement of the agreement.

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2013
Leases [Line Items]	'
Rent Expense for Operating Leases	'
	Rent expense for the years ended December 31 for operating leases was as follows:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
Future Minimum Rental Payments for All Operating Leases	'
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
PPL Energy Supply LLC [Member]	'
Leases [Line Items]	'
Rent Expense for Operating Leases	'
	Rent expense for the years ended December 31 for operating leases was as follows:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
Future Minimum Rental Payments for All Operating Leases	'
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
Future Minimum Rental Payments for All Operating Leases	'
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
Future Minimum Rental Payments for All Operating Leases	'
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45
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:
			2013		2012		2011
	PPL	$	111	$	116	$	109
	PPL Energy Supply		55		62		84
	LKE		18		18			18
	LG&E		7		7			7
	KU		10		10			10
Future Minimum Rental Payments for All Operating Leases	'
	Total future minimum rental payments for all operating leases are estimated to be:
				PPL
		PPL		Energy Supply		LKE			LG&E		KU
	2014	$	59	$	31	$	16		$	6	$	10
	2015		47		25		13			5		8
	2016		23		11		9			4		5
	2017		18		10		6			2		4
	2018		12		3		6			2		3
	Thereafter		42		3		29			12		15
	Total	$	201	$	83	$	79		$	31	$	45

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Stock-Based Compensation [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 was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
Restricted Stock and Restricted Stock Units, Activity Rollforward	'
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
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:
				2013		2012			2011
	PPL			$	19	$	27		$	19
	PPL Energy Supply				7		6			6
	PPL Electric				3		2			2
	LKE				1		4			1
Performance Units, Valuation Assumptions	'
	The weighted-average assumptions used in the model were:
					2013		2012			2011
	Risk-free interest rate				0.36%		0.30%			1.00%
	Expected stock volatility				15.50%		19.30%			23.40%
	Expected life				3 years		3 years			3 years
Performance Units, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of performance units granted was:
				2013		2012			2011
	PPL			$	34.15	$	31.41		$	29.67
	PPL Energy Supply				34.29		31.4			29.68
	PPL Electric				33.97		31.37			29.57
	LKE				33.84		31.3			29.2
Performance Units, Activity Rollforward	'
	Performance unit activity for 2013 was:
						Weighted-
						Average Grant
				Performance		Date Fair Value
				Units		Per Share
	PPL
	Nonvested, beginning of period				594,203	$	31.14
		Granted			348,495		34.15
		Forfeited			-149,499		32.63
	Nonvested, end of period				793,199		32.19
	PPL Energy Supply
	Nonvested, beginning of period				124,189	$	31.26
		Granted			74,614		34.29
		Forfeited			-28,194		33.47
	Nonvested, end of period				170,609		32.22
	PPL Electric
	Nonvested, beginning of period				26,083	$	31.1
		Granted			18,666		33.97
		Forfeited			-6,539		32.78
	Nonvested, end of period				38,210		32.22
	LKE
	Nonvested, beginning of period				82,750	$	30.62
		Granted			49,540		33.84
		Forfeited			-2,660		29.17
	Nonvested, end of period				129,630		31.88
Stock Options, Valuation Assumptions	'
	The assumptions used in the model were:
				2013		2012			2011
	Risk-free interest rate				1.15%		1.13%			2.34%
	Expected option life				6.48 years		6.17 years			5.71 years
	Expected stock volatility				18.50%		20.60%			21.60%
	Dividend yield				5.00%		5.00%			5.93%
Stock Options, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of options granted was:
				2013		2012			2011
	PPL			$	2.18	$	2.48		$	2.47
	PPL Energy Supply				2.19		2.51			2.47
	PPL Electric				2.19		2.5			2.47
	LKE				2.18		2.51			2.47
Stock Options, Activity Rollforward	'
	Stock option activity for 2013 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				9,134,545	$	30.36
		Granted			3,383,630		29.56
		Exercised			-1,136,693		27.13
	Outstanding at end of period				11,381,482		30.45			6.6		$	15
	Options exercisable at end of period				6,415,615		31.66			5			8
	PPL Energy Supply
	Outstanding at beginning of period				2,265,123	$	30.45
		Transferred			88,546		25.67
		Granted			713,030		29.66
		Exercised			-221,363		25.76
	Outstanding at end of period				2,845,336		30.47			6.2		$	4
	Options exercisable at end of period				1,747,842		31.48			4.6			2
	PPL Electric
	Outstanding at beginning of period				340,530	$	30.35
		Granted			191,670		29.49
	Outstanding at end of period				532,200		30.04			7.1		$	1
	Options exercisable at end of period				260,950		31.24			5.5
	LKE
	Outstanding at beginning of period				634,847	$	27.11
		Granted			501,950		29.51
		Exercised			-139,641		26.87
	Outstanding at end of period				997,156		28.35			8.4		$	2
	Options exercisable at end of period				250,682		27.22			7.7			1
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 was as follows:
				2013		2012			2011
	PPL			$	52	$	49		$	36
	PPL Energy Supply				27		23			16
	PPL Electric				10		11			8
	LKE				8		8			5
	The income tax benefit related to above compensation expense was as follows:
				2013		2012			2011
	PPL			$	22	$	20		$	15
	PPL Energy Supply				11		10			6
	PPL Electric				4		4			3
	LKE				3		4			2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	'
	At December 31, 2013, 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			$	33		1.9 years
	PPL Energy Supply				13		2.0 years
	PPL Electric				3		2.0 years
	LKE				2		1.7 years
PPL Energy Supply LLC [Member]	'
Stock-Based Compensation [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 was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
Restricted Stock and Restricted Stock Units, Activity Rollforward	'
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
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:
				2013		2012			2011
	PPL			$	19	$	27		$	19
	PPL Energy Supply				7		6			6
	PPL Electric				3		2			2
	LKE				1		4			1
Performance Units, Valuation Assumptions	'
	The weighted-average assumptions used in the model were:
					2013		2012			2011
	Risk-free interest rate				0.36%		0.30%			1.00%
	Expected stock volatility				15.50%		19.30%			23.40%
	Expected life				3 years		3 years			3 years
Performance Units, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of performance units granted was:
				2013		2012			2011
	PPL			$	34.15	$	31.41		$	29.67
	PPL Energy Supply				34.29		31.4			29.68
	PPL Electric				33.97		31.37			29.57
	LKE				33.84		31.3			29.2
Performance Units, Activity Rollforward	'
	Performance unit activity for 2013 was:
						Weighted-
						Average Grant
				Performance		Date Fair Value
				Units		Per Share
	PPL
	Nonvested, beginning of period				594,203	$	31.14
		Granted			348,495		34.15
		Forfeited			-149,499		32.63
	Nonvested, end of period				793,199		32.19
	PPL Energy Supply
	Nonvested, beginning of period				124,189	$	31.26
		Granted			74,614		34.29
		Forfeited			-28,194		33.47
	Nonvested, end of period				170,609		32.22
	PPL Electric
	Nonvested, beginning of period				26,083	$	31.1
		Granted			18,666		33.97
		Forfeited			-6,539		32.78
	Nonvested, end of period				38,210		32.22
	LKE
	Nonvested, beginning of period				82,750	$	30.62
		Granted			49,540		33.84
		Forfeited			-2,660		29.17
	Nonvested, end of period				129,630		31.88
Stock Options, Valuation Assumptions	'
	The assumptions used in the model were:
				2013		2012			2011
	Risk-free interest rate				1.15%		1.13%			2.34%
	Expected option life				6.48 years		6.17 years			5.71 years
	Expected stock volatility				18.50%		20.60%			21.60%
	Dividend yield				5.00%		5.00%			5.93%
Stock Options, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of options granted was:
				2013		2012			2011
	PPL			$	2.18	$	2.48		$	2.47
	PPL Energy Supply				2.19		2.51			2.47
	PPL Electric				2.19		2.5			2.47
	LKE				2.18		2.51			2.47
Stock Options, Activity Rollforward	'
	Stock option activity for 2013 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				9,134,545	$	30.36
		Granted			3,383,630		29.56
		Exercised			-1,136,693		27.13
	Outstanding at end of period				11,381,482		30.45			6.6		$	15
	Options exercisable at end of period				6,415,615		31.66			5			8
	PPL Energy Supply
	Outstanding at beginning of period				2,265,123	$	30.45
		Transferred			88,546		25.67
		Granted			713,030		29.66
		Exercised			-221,363		25.76
	Outstanding at end of period				2,845,336		30.47			6.2		$	4
	Options exercisable at end of period				1,747,842		31.48			4.6			2
	PPL Electric
	Outstanding at beginning of period				340,530	$	30.35
		Granted			191,670		29.49
	Outstanding at end of period				532,200		30.04			7.1		$	1
	Options exercisable at end of period				260,950		31.24			5.5
	LKE
	Outstanding at beginning of period				634,847	$	27.11
		Granted			501,950		29.51
		Exercised			-139,641		26.87
	Outstanding at end of period				997,156		28.35			8.4		$	2
	Options exercisable at end of period				250,682		27.22			7.7			1
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 was as follows:
				2013		2012			2011
	PPL			$	52	$	49		$	36
	PPL Energy Supply				27		23			16
	PPL Electric				10		11			8
	LKE				8		8			5
	The income tax benefit related to above compensation expense was as follows:
				2013		2012			2011
	PPL			$	22	$	20		$	15
	PPL Energy Supply				11		10			6
	PPL Electric				4		4			3
	LKE				3		4			2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	'
	At December 31, 2013, 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			$	33		1.9 years
	PPL Energy Supply				13		2.0 years
	PPL Electric				3		2.0 years
	LKE				2		1.7 years
PPL Electric Utilities Corp [Member]	'
Stock-Based Compensation [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 was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
Restricted Stock and Restricted Stock Units, Activity Rollforward	'
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
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:
				2013		2012			2011
	PPL			$	19	$	27		$	19
	PPL Energy Supply				7		6			6
	PPL Electric				3		2			2
	LKE				1		4			1
Performance Units, Valuation Assumptions	'
	The weighted-average assumptions used in the model were:
					2013		2012			2011
	Risk-free interest rate				0.36%		0.30%			1.00%
	Expected stock volatility				15.50%		19.30%			23.40%
	Expected life				3 years		3 years			3 years
Performance Units, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of performance units granted was:
				2013		2012			2011
	PPL			$	34.15	$	31.41		$	29.67
	PPL Energy Supply				34.29		31.4			29.68
	PPL Electric				33.97		31.37			29.57
	LKE				33.84		31.3			29.2
Performance Units, Activity Rollforward	'
	Performance unit activity for 2013 was:
						Weighted-
						Average Grant
				Performance		Date Fair Value
				Units		Per Share
	PPL
	Nonvested, beginning of period				594,203	$	31.14
		Granted			348,495		34.15
		Forfeited			-149,499		32.63
	Nonvested, end of period				793,199		32.19
	PPL Energy Supply
	Nonvested, beginning of period				124,189	$	31.26
		Granted			74,614		34.29
		Forfeited			-28,194		33.47
	Nonvested, end of period				170,609		32.22
	PPL Electric
	Nonvested, beginning of period				26,083	$	31.1
		Granted			18,666		33.97
		Forfeited			-6,539		32.78
	Nonvested, end of period				38,210		32.22
	LKE
	Nonvested, beginning of period				82,750	$	30.62
		Granted			49,540		33.84
		Forfeited			-2,660		29.17
	Nonvested, end of period				129,630		31.88
Stock Options, Valuation Assumptions	'
	The assumptions used in the model were:
				2013		2012			2011
	Risk-free interest rate				1.15%		1.13%			2.34%
	Expected option life				6.48 years		6.17 years			5.71 years
	Expected stock volatility				18.50%		20.60%			21.60%
	Dividend yield				5.00%		5.00%			5.93%
Stock Options, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of options granted was:
				2013		2012			2011
	PPL			$	2.18	$	2.48		$	2.47
	PPL Energy Supply				2.19		2.51			2.47
	PPL Electric				2.19		2.5			2.47
	LKE				2.18		2.51			2.47
Stock Options, Activity Rollforward	'
	Stock option activity for 2013 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				9,134,545	$	30.36
		Granted			3,383,630		29.56
		Exercised			-1,136,693		27.13
	Outstanding at end of period				11,381,482		30.45			6.6		$	15
	Options exercisable at end of period				6,415,615		31.66			5			8
	PPL Energy Supply
	Outstanding at beginning of period				2,265,123	$	30.45
		Transferred			88,546		25.67
		Granted			713,030		29.66
		Exercised			-221,363		25.76
	Outstanding at end of period				2,845,336		30.47			6.2		$	4
	Options exercisable at end of period				1,747,842		31.48			4.6			2
	PPL Electric
	Outstanding at beginning of period				340,530	$	30.35
		Granted			191,670		29.49
	Outstanding at end of period				532,200		30.04			7.1		$	1
	Options exercisable at end of period				260,950		31.24			5.5
	LKE
	Outstanding at beginning of period				634,847	$	27.11
		Granted			501,950		29.51
		Exercised			-139,641		26.87
	Outstanding at end of period				997,156		28.35			8.4		$	2
	Options exercisable at end of period				250,682		27.22			7.7			1
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 was as follows:
				2013		2012			2011
	PPL			$	52	$	49		$	36
	PPL Energy Supply				27		23			16
	PPL Electric				10		11			8
	LKE				8		8			5
	The income tax benefit related to above compensation expense was as follows:
				2013		2012			2011
	PPL			$	22	$	20		$	15
	PPL Energy Supply				11		10			6
	PPL Electric				4		4			3
	LKE				3		4			2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	'
	At December 31, 2013, 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			$	33		1.9 years
	PPL Energy Supply				13		2.0 years
	PPL Electric				3		2.0 years
	LKE				2		1.7 years
LG And E And KU Energy LLC [Member]	'
Stock-Based Compensation [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 was:
				2013		2012			2011
	PPL			$	30.3	$	28.35		$	25.25
	PPL Energy Supply				30.42		28.29			25.14
	PPL Electric				30.55		28.51			25.09
	LKE				30		28.34
Restricted Stock and Restricted Stock Units, Activity Rollforward	'
	Restricted stock and restricted stock unit activity for 2013 was:
						Weighted-
						Average
					Restricted	Grant Date Fair
					Shares/Units	Value Per Share
	PPL
	Nonvested, beginning of period				2,503,770	$	27.73
		Granted			1,307,951		30.3
		Vested			-638,421		29.19
		Forfeited			-32,700		28.61
	Nonvested, end of period				3,140,600		28.5
	PPL Energy Supply
	Nonvested, beginning of period				1,060,686	$	27.95
		Transferred			3,820		27.31
		Granted			527,440		30.42
		Vested			-236,382		29.1
		Forfeited			-12,160		29.04
	Nonvested, end of period				1,343,404		28.71
	PPL Electric
	Nonvested, beginning of period				261,228	$	27.3
		Transferred			-5,810		27.48
		Granted			108,990		30.55
		Vested			-94,008		28.41
		Forfeited			-4,850		28.61
	Nonvested, end of period				265,550		28.22
	LKE
	Nonvested, beginning of period				139,640	$	28.34
		Granted			127,293		30
		Vested			-35,380		28.87
	Nonvested, end of period				231,553		29.17
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:
				2013		2012			2011
	PPL			$	19	$	27		$	19
	PPL Energy Supply				7		6			6
	PPL Electric				3		2			2
	LKE				1		4			1
Performance Units, Valuation Assumptions	'
	The weighted-average assumptions used in the model were:
					2013		2012			2011
	Risk-free interest rate				0.36%		0.30%			1.00%
	Expected stock volatility				15.50%		19.30%			23.40%
	Expected life				3 years		3 years			3 years
Performance Units, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of performance units granted was:
				2013		2012			2011
	PPL			$	34.15	$	31.41		$	29.67
	PPL Energy Supply				34.29		31.4			29.68
	PPL Electric				33.97		31.37			29.57
	LKE				33.84		31.3			29.2
Performance Units, Activity Rollforward	'
	Performance unit activity for 2013 was:
						Weighted-
						Average Grant
				Performance		Date Fair Value
				Units		Per Share
	PPL
	Nonvested, beginning of period				594,203	$	31.14
		Granted			348,495		34.15
		Forfeited			-149,499		32.63
	Nonvested, end of period				793,199		32.19
	PPL Energy Supply
	Nonvested, beginning of period				124,189	$	31.26
		Granted			74,614		34.29
		Forfeited			-28,194		33.47
	Nonvested, end of period				170,609		32.22
	PPL Electric
	Nonvested, beginning of period				26,083	$	31.1
		Granted			18,666		33.97
		Forfeited			-6,539		32.78
	Nonvested, end of period				38,210		32.22
	LKE
	Nonvested, beginning of period				82,750	$	30.62
		Granted			49,540		33.84
		Forfeited			-2,660		29.17
	Nonvested, end of period				129,630		31.88
Stock Options, Valuation Assumptions	'
	The assumptions used in the model were:
				2013		2012			2011
	Risk-free interest rate				1.15%		1.13%			2.34%
	Expected option life				6.48 years		6.17 years			5.71 years
	Expected stock volatility				18.50%		20.60%			21.60%
	Dividend yield				5.00%		5.00%			5.93%
Stock Options, Weighted Average Grant Date Fair Value	'
	The weighted-average grant date fair value of options granted was:
				2013		2012			2011
	PPL			$	2.18	$	2.48		$	2.47
	PPL Energy Supply				2.19		2.51			2.47
	PPL Electric				2.19		2.5			2.47
	LKE				2.18		2.51			2.47
Stock Options, Activity Rollforward	'
	Stock option activity for 2013 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				9,134,545	$	30.36
		Granted			3,383,630		29.56
		Exercised			-1,136,693		27.13
	Outstanding at end of period				11,381,482		30.45			6.6		$	15
	Options exercisable at end of period				6,415,615		31.66			5			8
	PPL Energy Supply
	Outstanding at beginning of period				2,265,123	$	30.45
		Transferred			88,546		25.67
		Granted			713,030		29.66
		Exercised			-221,363		25.76
	Outstanding at end of period				2,845,336		30.47			6.2		$	4
	Options exercisable at end of period				1,747,842		31.48			4.6			2
	PPL Electric
	Outstanding at beginning of period				340,530	$	30.35
		Granted			191,670		29.49
	Outstanding at end of period				532,200		30.04			7.1		$	1
	Options exercisable at end of period				260,950		31.24			5.5
	LKE
	Outstanding at beginning of period				634,847	$	27.11
		Granted			501,950		29.51
		Exercised			-139,641		26.87
	Outstanding at end of period				997,156		28.35			8.4		$	2
	Options exercisable at end of period				250,682		27.22			7.7			1
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 was as follows:
				2013		2012			2011
	PPL			$	52	$	49		$	36
	PPL Energy Supply				27		23			16
	PPL Electric				10		11			8
	LKE				8		8			5
	The income tax benefit related to above compensation expense was as follows:
				2013		2012			2011
	PPL			$	22	$	20		$	15
	PPL Energy Supply				11		10			6
	PPL Electric				4		4			3
	LKE				3		4			2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	'
	At December 31, 2013, 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			$	33		1.9 years
	PPL Energy Supply				13		2.0 years
	PPL Electric				3		2.0 years
	LKE				2		1.7 years

Retirement_and_Postemployment_1

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2013
Net Periodic Defined Benefit Costs (Credits) [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 (U.K.) pension and other postretirement benefit plans for the years ended December 31.
					Pension Benefits
					U.S.									U.K.									Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011			2013			2012			2011
	Net periodic defined benefit costs
		(credits):
	Service cost				$	126		$	103		$	95		$	69		$	54		$	44		$	14		$	12		$	12
	Interest cost					213			220			217			320			340			282			29			31			33
	Expected return on plan assets					-293			-259			-245			-465			-458			-338			-25			-23			-23
	Amortization of:
			Transition (asset) obligation																								2			2
			Prior service cost (credit)			22			24			24			1			4			4						1
			Actuarial (gain) loss			80			42			30			150			79			57			6			4			6
	Net periodic defined benefit costs
		(credits) prior to settlement
		charges and termination benefits				148			130			121			75			19			49			24			27			30
	Settlement charges								11
	Termination benefits (a)														3			2			50
	Net periodic defined benefit costs
		(credits)			$	148		$	141		$	121		$	78		$	21		$	99		$	24		$	27		$	30
	Other Changes in Plan Assets
		and Benefit Obligations
		Recognized in OCI and
		Regulatory Assets/Liabilities -
		Gross:
	Settlements							$	-11
	Net (gain) loss				$	-319			372		$	117		$	76		$	1,073		$	152		$	-68		$	13		$	-9
	Prior service cost
		(credit)										8												-3			-1			10
	Amortization of:
			Transition asset (obligation)																								-2			-2
			Prior service (cost) credit			-22			-24			-24			-1			-4			-4						-1
			Actuarial gain (loss)			-80			-42			-30			-150			-79			-57			-6			-4			-6
	Total recognized in OCI and
		regulatory assets/liabilities (b)				-421			295			71			-75			990			91			-77			5			-7
	Total recognized in net periodic
		defined benefit costs, OCI and
		regulatory assets/liabilities (b)			$	-273		$	436		$	192		$	3		$	1,011		$	190		$	-53		$	32		$	23
	(a)       Related to the WPD Midlands separations in the U.K.
	(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 recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows:
				U.S. Pension Benefits										Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011
	OCI			$	-228		$	181		$	47		$	-41		$	12		$	-6
	Regulatory assets/liabilities				-193			114			24			-36			-7			-1
	Total recognized in OCI and
		regulatory assets/liabilities		$	-421		$	295		$	71		$	-77		$	5		$	-7
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 benefit costs in 2014 are as follows:
			Pension Benefits
			U.S.			U.K.
	Prior service cost (credit)		$	20
	Actuarial (gain) loss			30		$	131
	Total		$	50		$	131
	Amortization from Balance Sheet:
	AOCI		$	22		$	131
	Regulatory assets/liabilities			28
	Total		$	50		$	131
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	'
	The following net periodic defined benefit costs (credits) were charged to operating expense, 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
			2013			2012			2011			2013			2012			2011			2013			2012			2011
	PPL		$	117		$	119		$	98		$	33		$	25		$	82		$	19		$	22		$	24
	PPL Energy Supply			45			37			27												6			6			7
	PPL Electric (a)			18			19			14												3			3			4
	LKE			32			31			40												8			9			11
	LG&E			14			13			16												4			5			5
	KU (a)			9			8			10												2			3			4
	(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.
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.
				Pension Benefits
				U.S.						U.K.						Other Postretirement Benefits
				2013			2012			2013			2012			2013			2012
	PPL
		Discount rate			5.12%			4.22%			4.41%			4.27%			4.91%			4.00%
		Rate of compensation increase			3.97%			3.98%			4.00%			4.00%			3.96%			3.97%
	PPL Energy Supply
		Discount rate			5.18%			4.25%									4.51%			3.77%
		Rate of compensation increase			3.94%			3.95%									3.94%			3.95%
	LKE
		Discount rate			5.18%			4.24%									4.91%			3.99%
		Rate of compensation increase			4.00%			4.00%									4.00%			4.00%
	LG&E
		Discount rate			5.13%			4.20%
	The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31.
				Pension Benefits
				U.S.									U.K.									Other Postretirement Benefits
				2013			2012			2011			2013			2012			2011			2013			2012			2011
	PPL
		Discount rate			4.22%			5.06%			5.42%			4.27%			5.24%			5.59%			4.00%			4.80%			5.14%
		Rate of compensation increase			3.98%			4.02%			4.88%			4.00%			4.00%			3.75%			3.97%			4.00%			4.90%
		Expected return on plan assets (a)			7.03%			7.07%			7.25%			7.16%			7.17%			7.04%			5.94%			5.99%			6.57%
	PPL Energy Supply
		Discount rate			4.25%			5.12%			5.47%												3.77%			4.60%			4.95%
		Rate of compensation increase			3.95%			4.00%			4.75%												3.95%			4.00%			4.75%
		Expected return on plan assets (a)			7.00%			7.00%			7.25%												N/A			N/A			N/A
	LKE
		Discount rate			4.24%			5.09%			5.49%												3.99%			4.78%			5.12%
		Rate of compensation increase			4.00%			4.00%			5.25%												4.00%			4.00%			5.25%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%												6.76%			7.02%			7.16%
	LG&E
		Discount rate			4.20%			5.00%			5.39%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%
	(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, PPL Energy Supply and LKE)
	The following table provides the assumed health care cost trend rates for the years ended December 31:
						2013			2012			2011
	PPL and PPL Energy Supply
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
	LKE
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
	A one percentage point change in the assumed health care costs trend rate assumption would have had the following effects on the other postretirement benefit plans in 2013:
				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
					2013			2012			2013			2012			2013			2012
	Change in Benefit Obligation
	Benefit Obligation, beginning of period				$	5,046		$	4,381		$	7,888		$	6,638		$	722		$	687
			Service cost			126			103			69			54			14			12
			Interest cost			213			220			320			340			29			31
			Participant contributions									15			15			12			6
			Plan amendments															-4			-1
			Actuarial (gain) loss			-540			546			46			1,081			-54			31
			Settlements						-25
			Termination benefits									3			2
			Net transfer in (out)												12
			Actual expenses paid						-3
			Gross benefits paid (a)			-254			-176			-375			-397			-57			-46
			Federal subsidy																		2
			Currency conversion									177			143
	Benefit Obligation, end of period					4,591			5,046			8,143			7,888			662			722
	Change in Plan Assets
	Plan assets at fair value, beginning of period					3,939			3,471			6,911			6,351			421			391
			Actual return on plan assets			72			432			438			476			37			42
			Employer contributions			399			239			134			341			30			27
			Participant contributions									15			15			12			5
			Settlements						-25
			Actual expenses paid						-2
			Gross benefits paid (a)			-254			-176			-375			-397			-54			-44
			Currency conversion									161			125
	Plan assets at fair value, end of period					4,156			3,939			7,284			6,911			446			421
	Funded Status, end of period				$	-435		$	-1,107		$	-859		$	-977		$	-216		$	-301
	Amounts recognized in the Balance
		Sheets consist of:
			Current liability		$	-8		$	-8								$	-1		$	-1
			Noncurrent liability			-427			-1,099		$	-859		$	-977			-215			-300
	Net amount recognized, end of period				$	-435		$	-1,107		$	-859		$	-977		$	-216		$	-301
	Amounts recognized in AOCI and
		regulatory assets/liabilities (pre-tax)
		consist of:
	Prior service cost (credit)				$	69		$	91					$	1		$	-11		$	-7
	Net actuarial (gain) loss					842			1,241		$	2,112			2,184			33			106
	Total (b)				$	911		$	1,332		$	2,112		$	2,185		$	22		$	99
	Total accumulated benefit obligation
		for defined benefit pension plans			$	4,191		$	4,569		$	7,542		$	7,259
	(a)       Certain U.S. pension plans offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump sum payment. The increase in gross benefits paid is primarily the result of $64 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with these offerings.
	(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 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
				2013			2012			2013			2012
	AOCI			$	430		$	659		$	19		$	59
	Regulatory assets/liabilities				481			673			3			40
	Total			$	911		$	1,332		$	22		$	99
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
				2013			2012			2013			2012
	Projected benefit obligation		$	4,591		$	5,046		$	8,143		$	7,888
	Fair value of plan assets			4,156			3,939			7,284			6,911
			U.S.						U.K.
			ABO in excess of plan assets						ABO in excess of plan assets
				2013			2012			2013			2012
	Accumulated benefit obligation		$	572		$	4,569		$	3,441		$	3,349
	Fair value of plan assets			431			3,939			3,131			2,812
Contributions Made to Multiemployer Plans	'
	The table below details total contributions to all multiemployer pension and other postretirement plans, including the plan identified as significant above.
			2013			2012			2011
	Pension Plans		$	36		$	31		$	36
	Other Postretirement Benefit Plans			32			28			31
	Total Contributions		$	68		$	59		$	67
Schedules of Asset Allocation of U.S. Pension Trusts Assets	'
	The asset allocation for the trusts and the target allocation by portfolio, at December 31, are as follows:
										2013 Target Asset Allocation (a)
				Percentage of trust assets							Weighted
					2013 (a)			2012			Average			PPL Plans			LKE Plans
	Growth Portfolio				59%			58%			55%			55%			55%
		Equity securities			30%			31%
		Debt securities (b)			17%			18%
		Alternative investments			12%			9%
	Immunizing Portfolio				39%			41%			43%			43%			43%
		Debt securities (b)			40%			40%
		Derivatives			-1%			1%
	Liquidity Portfolio				2%			1%			2%			2%			2%
	Total				100%			100%			100%			100%			100%
	(a)       Allocations exclude consideration of cash for the WKE Bargaining Employees' Retirement Plan and a guaranteed 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 U.S. pension plan trusts by asset class and level within the fair value hierarchy was:
						December 31, 2013												December 31, 2012
									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					$	120		$	120								$	84		$	84
	Equity securities:
			U.S.:
				Large-cap			480			134		$	346						558			206		$	352
				Small-cap			137			137									124			124
				Commingled debt			749			13			736						676			56			620
			International				630			163			467						557			184			373
	Debt securities:
			U.S. Treasury and U.S. government sponsored
				agency			617			563			54						704			634			70
			Residential/commercial backed securities				12						11		$	1			12						11		$	1
			Corporate				963						940			23			874						847			27
			Other				24						24						24						23			1
			International				7						7						7						7
	Alternative investments:
			Commodities				108						108						59						59
			Real estate				134						134						93						93
			Private equity				80									80			75									75
			Hedge funds				210						210						125						125
	Derivatives:
			Interest rate swaps and swaptions				-49						-49						36						36
			Other				12						12						2						2
	Insurance contracts						37									37			42									42
	PPL Services Corporation Master Trust assets, at
		fair value					4,271		$	1,130		$	3,000		$	141			4,052		$	1,288		$	2,618		$	146
	Receivables and payables, net (a)																		-11
	401(h) account restricted for other
		postretirement benefit obligations					-115												-102
	Total PPL Services Corporation Master Trust
		pension assets				$	4,156											$	3,939
	(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	'
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2013 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period						$	1		$	27		$	75		$	42		$	1		$	146
		Actual return on plan assets
				Relating to assets still held
					at the reporting date									3			2						5
				Relating to assets sold during the period							5												5
		Purchases, sales and settlements									-9			2			-7						-14
		Transfers from level 3 to level 2																		-1			-1
	Balance at end of period						$	1		$	23		$	80		$	37		$			$	141
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2012 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period									$	7		$	45		$	46					$	98
		Actual return on plan assets
				Relating to assets still held
					at the reporting date						1			10			3						14
				Relating to assets sold during the period							2												2
		Purchases, sales and settlements					$	1			21			20			-7						35
		Transfers from level 2 to level 3																	$	1			1
		Transfers from level 3 to level 2									-4												-4
	Balance at end of period						$	1		$	27		$	75		$	42		$	1		$	146
Schedules of Target Allocation of U.S. Other Postretirement Benefit Plans VEBA Trust	'
	The asset allocation for the PPL VEBA trusts, excluding LKE, and the target allocation, by asset class, at December 31 are detailed below.
										Target Asset
				Percentage of plan assets						Allocation
				2013			2012			2013
	Asset Class
	U.S. Equity securities				55%			46%			45%
	Debt securities (a)				41%			51%			50%
	Cash and cash equivalents (b)				4%			3%			5%
		Total			100%			100%			100%
	(a)       Includes commingled debt funds and debt securities.
	(b)       Includes money market funds.
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	'
	The fair value of assets in the U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was:
						December 31, 2013												December 31, 2012
									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					$	12		$	12								$	13		$	13
	U.S. Equity securities:
			Large-cap				182					$	182						145					$	145
			Commingled debt				100						100						119						119
	Debt securities:
			Municipalities				36						36						41						41
	Total VEBA trust assets, at fair value						330		$	12		$	318						318		$	13		$	305
	Receivables and payables, net (a)						1												1
	401(h) account assets (b)						115												102
	Total other postretirement benefit plan
		assets				$	446											$	421
	(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
	(b)       LKE's other postretirement benefit plan was invested primarily in a 401(h) account as disclosed in the PPL Services Corporation Master Trust.
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
				2013			2012			2013
	Asset Class
	Equity securities
		U.K.			7%			6%			7%
		European (excluding the U.K.)			5%			14%			4%
		Asian-Pacific			3%						3%
		North American			5%						5%
		Emerging markets			8%			3%			8%
		Currency			7%			2%			3%
		Global Tactical Asset Allocation			19%			18%			19%
	Debt securities (a)				40%			51%			45%
	Alternative investments				6%			6%			6%
		Total			100%			100%			100%
	(a)       Includes commingled debt funds.
Schedule of Fair Value of Financial Assets for U.K. Pension Plan Assets	'
	The fair value of assets in the U.K. pension plans by asset class and level within the fair value hierarchy was:
						December 31, 2013												December 31, 2012
									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					$	10		$	10								$	14		$	14
	Equity securities:
			U.K. companies				523			267		$	256						440			223		$	217
			European companies (excluding the U.K.)				355			275			80						956			720			236
			Asian-Pacific companies				226			180			46
			North American companies				352			254			98
			Emerging markets companies				411			126			285						231						231
			Global Equities				161						161
			Currency				485						485						127						127
			Global Tactical Asset Allocation				1,384						1,384						1,220						1,220
			Commingled debt:
				U.K. corporate bonds			504						504						593						593
				U.K. gilts			2,426						2,426						2,907						2,907
	Alternative investments:
			Real estate				447						447						423						423
	Fair value - U.K. pension plans					$	7,284		$	1,112		$	6,172					$	6,911		$	957		$	5,954
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
	2014		$	211		$	53		$	1
	2015			222			55			1
	2016			234			57			1
	2017			250			59			1
	2018			264			62			1
	2019-2023			1,545			338			3
Schedule of Expected Cash Flows - U.K. Pension Plans - Expected Payments	'
	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans.
			Pension
	2014		$	387
	2015			392
	2016			397
	2017			402
	2018			410
	2019-2023			2,128
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:
			2013			2012			2011
	PPL		$	41		$	36		$	31
	PPL Energy Supply			12			12			11
	PPL Electric			6			5			5
	LKE			13			12			11
	LG&E			7			6			5
	KU			6			6			6
PPL Energy Supply LLC [Member]	'
Net Periodic Defined Benefit Costs (Credits) [Line Items]	'
Schedule Of Net Periodic Defined Benefit Costs (Credits)	'
	The following table provides the components of net periodic defined benefit costs for PPL Energy Supply's pension and other postretirement benefit plans for the years ended December 31.
					Pension Benefits									Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011
	Net periodic defined benefit costs
	(credits):
	Service cost				$	7		$	6		$	5		$	1		$	1		$	1
	Interest cost					8			7			7						1			1
	Expected return on plan assets					-10			-9			-9
	Amortization of:
			Actuarial (gain) loss			3			2			2
	Net periodic defined benefit costs
		(credits)			$	8		$	6		$	5		$	1		$	2		$	2
	Other Changes in Plan Assets
		and Benefit Obligations
		Recognized in OCI:
	Net (gain) loss				$	-15		$	16		$	7		$	-1					$	-2
	Prior service cost (credit)														-3		$	-1
	Amortization of:
			Actuarial gain (loss)			-3			-2			-2
	Total recognized in OCI					-18			14			5			-4			-1			-2
	Total recognized in net periodic
		defined benefit costs and OCI			$	-10		$	20		$	10		$	-3		$	1		$
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	'
	In the table above, for PPL Energy Supply and LG&E, amounts include costs for the specific plans each sponsors and the following allocated costs of defined benefit plans sponsored by PPL Services (for PPL Energy Supply) and by LKE (for LG&E), based on their participation in those plans, which management believes are reasonable:
					Pension Benefits										Other Postretirement Benefits
						2013			2012			2011			2013			2012			2011
	PPL Energy Supply				$	38		$	31		$	23		$	5		$	5		$	6
	LG&E			5			5			7			4			5			5
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.
				Pension Benefits
				U.S.						U.K.						Other Postretirement Benefits
				2013			2012			2013			2012			2013			2012
	PPL
		Discount rate			5.12%			4.22%			4.41%			4.27%			4.91%			4.00%
		Rate of compensation increase			3.97%			3.98%			4.00%			4.00%			3.96%			3.97%
	PPL Energy Supply
		Discount rate			5.18%			4.25%									4.51%			3.77%
		Rate of compensation increase			3.94%			3.95%									3.94%			3.95%
	LKE
		Discount rate			5.18%			4.24%									4.91%			3.99%
		Rate of compensation increase			4.00%			4.00%									4.00%			4.00%
	LG&E
		Discount rate			5.13%			4.20%
	The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31.
				Pension Benefits
				U.S.									U.K.									Other Postretirement Benefits
				2013			2012			2011			2013			2012			2011			2013			2012			2011
	PPL
		Discount rate			4.22%			5.06%			5.42%			4.27%			5.24%			5.59%			4.00%			4.80%			5.14%
		Rate of compensation increase			3.98%			4.02%			4.88%			4.00%			4.00%			3.75%			3.97%			4.00%			4.90%
		Expected return on plan assets (a)			7.03%			7.07%			7.25%			7.16%			7.17%			7.04%			5.94%			5.99%			6.57%
	PPL Energy Supply
		Discount rate			4.25%			5.12%			5.47%												3.77%			4.60%			4.95%
		Rate of compensation increase			3.95%			4.00%			4.75%												3.95%			4.00%			4.75%
		Expected return on plan assets (a)			7.00%			7.00%			7.25%												N/A			N/A			N/A
	LKE
		Discount rate			4.24%			5.09%			5.49%												3.99%			4.78%			5.12%
		Rate of compensation increase			4.00%			4.00%			5.25%												4.00%			4.00%			5.25%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%												6.76%			7.02%			7.16%
	LG&E
		Discount rate			4.20%			5.00%			5.39%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%
	(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, PPL Energy Supply and LKE)
	The following table provides the assumed health care cost trend rates for the years ended December 31:
						2013			2012			2011
	PPL and PPL Energy Supply
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
	LKE
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
Schedule of Funded Status of Defined Benefit Plans	'
	(PPL Energy Supply)
	The funded status of PPL Energy Supply's plans at December 31 was as follows:
					Pension Benefits
					U.S.						Other Postretirement Benefits
					2013			2012			2013			2012
	Change in Benefit Obligation
	Benefit Obligation, beginning of period				$	176		$	143		$	17		$	17
			Service cost			7			6			1			1
			Interest cost			8			7						1
			Plan amendments									-4			-1
			Actuarial (gain) loss			-23			23			-1
			Gross benefits paid			-5			-3			-1			-1
	Benefit Obligation, end of period					163			176			12			17
	Change in Plan Assets
	Plan assets at fair value, beginning of
		period				149			132
			Actual return on plan assets			3			16
			Employer contributions						4			1
			Gross benefits paid			-5			-3			-1
	Plan assets at fair value, end of period					147			149
	Funded Status, end of period				$	-16		$	-27		$	-12		$	-17
	Amounts recognized in the Balance
		Sheets consist of:
			Current liability								$	-1		$	-1
			Noncurrent liability		$	-16		$	-27			-11			-16
	Net amount recognized, end of period				$	-16		$	-27		$	-12		$	-17
	Amounts recognized in AOCI
		(pre-tax) consist of:
	Prior service cost (credit)										$	-5		$	-1
	Net actuarial (gain) loss				$	34		$	52			1			2
	Total				$	34		$	52		$	-4		$	1
	Total accumulated benefit obligation
		for defined benefit pension plans			$	163		$	176
	Allocations to PPL Energy Supply resulted in liabilities at December 31 as follows:
			2013			2012
	Pension		$	96		$	268
	Other postretirement benefits			35			60
Contributions Made to Multiemployer Plans	'
	The table below details total contributions to all multiemployer pension and other postretirement plans, including the plan identified as significant above.
			2013			2012			2011
	Pension Plans		$	36		$	31		$	36
	Other Postretirement Benefit Plans			32			28			31
	Total Contributions		$	68		$	59		$	67
Schedules of Asset Allocation of U.S. Pension Trusts Assets	'
	The asset allocation for the trusts and the target allocation by portfolio, at December 31, are as follows:
										2013 Target Asset Allocation (a)
				Percentage of trust assets							Weighted
					2013 (a)			2012			Average			PPL Plans			LKE Plans
	Growth Portfolio				59%			58%			55%			55%			55%
		Equity securities			30%			31%
		Debt securities (b)			17%			18%
		Alternative investments			12%			9%
	Immunizing Portfolio				39%			41%			43%			43%			43%
		Debt securities (b)			40%			40%
		Derivatives			-1%			1%
	Liquidity Portfolio				2%			1%			2%			2%			2%
	Total				100%			100%			100%			100%			100%
	(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 U.S. pension plan trusts by asset class and level within the fair value hierarchy was:
						December 31, 2013												December 31, 2012
									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					$	120		$	120								$	84		$	84
	Equity securities:
			U.S.:
				Large-cap			480			134		$	346						558			206		$	352
				Small-cap			137			137									124			124
				Commingled debt			749			13			736						676			56			620
			International				630			163			467						557			184			373
	Debt securities:
			U.S. Treasury and U.S. government sponsored
				agency			617			563			54						704			634			70
			Residential/commercial backed securities				12						11		$	1			12						11		$	1
			Corporate				963						940			23			874						847			27
			Other				24						24						24						23			1
			International				7						7						7						7
	Alternative investments:
			Commodities				108						108						59						59
			Real estate				134						134						93						93
			Private equity				80									80			75									75
			Hedge funds				210						210						125						125
	Derivatives:
			Interest rate swaps and swaptions				-49						-49						36						36
			Other				12						12						2						2
	Insurance contracts						37									37			42									42
	PPL Services Corporation Master Trust assets, at
		fair value					4,271		$	1,130		$	3,000		$	141			4,052		$	1,288		$	2,618		$	146
	Receivables and payables, net (a)																		-11
	401(h) account restricted for other
		postretirement benefit obligations					-115												-102
	Total PPL Services Corporation Master Trust
		pension assets				$	4,156											$	3,939
	(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	'
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2013 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period						$	1		$	27		$	75		$	42		$	1		$	146
		Actual return on plan assets
				Relating to assets still held
					at the reporting date									3			2						5
				Relating to assets sold during the period							5												5
		Purchases, sales and settlements									-9			2			-7						-14
		Transfers from level 3 to level 2																		-1			-1
	Balance at end of period						$	1		$	23		$	80		$	37		$			$	141
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2012 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period									$	7		$	45		$	46					$	98
		Actual return on plan assets
				Relating to assets still held
					at the reporting date						1			10			3						14
				Relating to assets sold during the period							2												2
		Purchases, sales and settlements					$	1			21			20			-7						35
		Transfers from level 2 to level 3																	$	1			1
		Transfers from level 3 to level 2									-4												-4
	Balance at end of period						$	1		$	27		$	75		$	42		$	1		$	146
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.
						Other
			Pension			Postretirement
	2014		$	5		$	1
	2015			6			2
	2016			6			2
	2017			7			2
	2018			8			2
	2019-2023			52			11
PPL Electric Utilities Corp [Member]	'
Net Periodic Defined Benefit Costs (Credits) [Line Items]	'
Schedule of Funded Status of Defined Benefit Plans	'
	Allocations to PPL Electric resulted in liabilities at December 31 as follows.
			2013			2012
	Pension		$	96		$	237
	Other postretirement benefits			41			61
LG And E And KU Energy LLC [Member]	'
Net Periodic Defined Benefit Costs (Credits) [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
					2013			2012			2011			2013			2012			2011
	Net periodic defined benefit costs
		(credits):
	Service cost				$	26		$	22		$	24		$	5		$	4		$	4
	Interest cost					62			64			67			8			9			10
	Expected return on plan assets					-82			-70			-64			-5			-4			-3
	Amortization of:
			Transition (asset) obligation															2			2
			Prior service cost (credit)			5			5			5			3			3			2
			Actuarial (gain) loss			33			22			24						-1
	Net periodic defined benefit costs (credits)				$	44		$	43		$	56		$	11		$	13		$	15
	Other Changes in Plan Assets
		and Benefit Obligations
		Recognized in OCI and
		Regulatory Assets/Liabilities -
		Gross:
	Net (gain) loss				$	-116		$	96		$	29		$	-14		$	-11		$	-3
	Prior service cost (credit)											8									11
	Amortization of:
			Transition (asset) obligation															-2			-2
			Prior service (cost) credit			-5			-5			-5			-3			-3			-2
			Actuarial gain (loss)			-33			-22			-24						1
	Total recognized in OCI and
		regulatory assets/liabilities				-154			69			8			-17			-15			4
	Total recognized in net periodic
		defined benefit costs, OCI and regulatory
		assets/liabilities			$	-110		$	112		$	64		$	-6		$	-2		$	19
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	'
	For LKE's pension and other postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows:
					Pension Benefits									Other Postretirement Benefits
					2013			2012			2011			2013			2012			2011
		OCI			$	-46		$	34		$	1		$	-1		$	-1		$	2
		Regulatory assets/liabilities				-108			35			7			-16			-14			2
		Total recognized in OCI and
			regulatory assets/liabilities		$	-154		$	69		$	8		$	-17		$	-15		$	4
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/liabilities into net periodic defined benefit costs for LKE in 2014 are as follows.
						Other
			Pension			Postretirement
			Benefits			Benefits
	Prior service cost (credit)		$	5		$	2
	Actuarial (gain) loss			13			-1
	Total		$	18		$	1
	Amortization from Balance Sheet:
	Regulatory assets/liabilities		$	18		$	1
	Total		$	18		$	1
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.
				Pension Benefits
				U.S.						U.K.						Other Postretirement Benefits
				2013			2012			2013			2012			2013			2012
	PPL
		Discount rate			5.12%			4.22%			4.41%			4.27%			4.91%			4.00%
		Rate of compensation increase			3.97%			3.98%			4.00%			4.00%			3.96%			3.97%
	PPL Energy Supply
		Discount rate			5.18%			4.25%									4.51%			3.77%
		Rate of compensation increase			3.94%			3.95%									3.94%			3.95%
	LKE
		Discount rate			5.18%			4.24%									4.91%			3.99%
		Rate of compensation increase			4.00%			4.00%									4.00%			4.00%
	LG&E
		Discount rate			5.13%			4.20%
	The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31.
				Pension Benefits
				U.S.									U.K.									Other Postretirement Benefits
				2013			2012			2011			2013			2012			2011			2013			2012			2011
	PPL
		Discount rate			4.22%			5.06%			5.42%			4.27%			5.24%			5.59%			4.00%			4.80%			5.14%
		Rate of compensation increase			3.98%			4.02%			4.88%			4.00%			4.00%			3.75%			3.97%			4.00%			4.90%
		Expected return on plan assets (a)			7.03%			7.07%			7.25%			7.16%			7.17%			7.04%			5.94%			5.99%			6.57%
	PPL Energy Supply
		Discount rate			4.25%			5.12%			5.47%												3.77%			4.60%			4.95%
		Rate of compensation increase			3.95%			4.00%			4.75%												3.95%			4.00%			4.75%
		Expected return on plan assets (a)			7.00%			7.00%			7.25%												N/A			N/A			N/A
	LKE
		Discount rate			4.24%			5.09%			5.49%												3.99%			4.78%			5.12%
		Rate of compensation increase			4.00%			4.00%			5.25%												4.00%			4.00%			5.25%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%												6.76%			7.02%			7.16%
	LG&E
		Discount rate			4.20%			5.00%			5.39%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%
	(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, PPL Energy Supply and LKE)
	The following table provides the assumed health care cost trend rates for the years ended December 31:
						2013			2012			2011
	PPL and PPL Energy Supply
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
	LKE
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
	A one percentage point change in the assumed health care costs trend rate assumption would have had the following effects on the other postretirement benefit plans in 2013:
				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
					2013			2012			2013			2012
	Change in Benefit Obligation
	Benefit Obligation, beginning of period				$	1,487		$	1,306		$	209		$	214
			Service cost			26			22			5			4
			Interest cost			62			63			8			9
			Participant contributions									7			8
			Actuarial (gain) loss			-177			144			-18			-8
			Gross benefits paid (a)			-70			-48			-18			-19
			Federal subsidy												1
	Benefit Obligation, end of period					1,328			1,487			193			209
	Change in Plan Assets
	Plan assets at fair value, beginning of period					1,070			944			68			58
			Actual return on plan assets			21			117			1			8
			Employer contributions			152			57			16			13
			Participant contributions									7			8
			Gross benefits paid (a)			-70			-48			-18			-19
	Plan assets at fair value, end of period					1,173			1,070			74			68
	Funded Status, end of period				$	-155		$	-417		$	-119		$	-141
	Amounts recognized in the Balance
		Sheets consist of:
			Current liability		$	-3		$	-3
			Noncurrent liability			-152			-414		$	-119		$	-141
	Net amount recognized, end of period				$	-155		$	-417		$	-119		$	-141
	Amounts recognized in AOCI and
		regulatory assets/liabilities (pre-tax)
		consist of:
	Prior service cost (credit)				$	24		$	28		$	8		$	11
	Net actuarial (gain) loss					205			355			-30			-17
	Total				$	229		$	383		$	-22		$	-6
	Total accumulated benefit obligation
		for defined benefit pension plans			$	1,176		$	1,319
	(a)       Certain LKE pension plans offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The increase in gross benefits paid is primarily the result of $21 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with these offerings.
	The amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows:
				Pension Benefits						Other Postretirement Benefits
				2013			2012			2013			2012
		AOCI		$	-19		$	27
		Regulatory assets/liabilities			248			356		$	-22		$	-6
		Total		$	229		$	383		$	-22		$	-6
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:
			PBO in excess of plan assets
				2013			2012
	Projected benefit obligation		$	1,328		$	1,487
	Fair value of plan assets			1,173			1,070
			ABO in excess of plan assets
				2013			2012
	Accumulated benefit obligation		$	350		$	1,319
	Fair value of plan assets			284			1,070
Schedules of Asset Allocation of U.S. Pension Trusts Assets	'
	The asset allocation for the trusts and the target allocation by portfolio, at December 31, are as follows:
										2013 Target Asset Allocation (a)
				Percentage of trust assets							Weighted
					2013 (a)			2012			Average			PPL Plans			LKE Plans
	Growth Portfolio				59%			58%			55%			55%			55%
		Equity securities			30%			31%
		Debt securities (b)			17%			18%
		Alternative investments			12%			9%
	Immunizing Portfolio				39%			41%			43%			43%			43%
		Debt securities (b)			40%			40%
		Derivatives			-1%			1%
	Liquidity Portfolio				2%			1%			2%			2%			2%
	Total				100%			100%			100%			100%			100%
	(a)       Allocations exclude consideration of cash for the WKE Bargaining Employees' Retirement Plan and a guaranteed 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 U.S. pension plan trusts by asset class and level within the fair value hierarchy was:
						December 31, 2013												December 31, 2012
									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					$	120		$	120								$	84		$	84
	Equity securities:
			U.S.:
				Large-cap			480			134		$	346						558			206		$	352
				Small-cap			137			137									124			124
				Commingled debt			749			13			736						676			56			620
			International				630			163			467						557			184			373
	Debt securities:
			U.S. Treasury and U.S. government sponsored
				agency			617			563			54						704			634			70
			Residential/commercial backed securities				12						11		$	1			12						11		$	1
			Corporate				963						940			23			874						847			27
			Other				24						24						24						23			1
			International				7						7						7						7
	Alternative investments:
			Commodities				108						108						59						59
			Real estate				134						134						93						93
			Private equity				80									80			75									75
			Hedge funds				210						210						125						125
	Derivatives:
			Interest rate swaps and swaptions				-49						-49						36						36
			Other				12						12						2						2
	Insurance contracts						37									37			42									42
	PPL Services Corporation Master Trust assets, at
		fair value					4,271		$	1,130		$	3,000		$	141			4,052		$	1,288		$	2,618		$	146
	Receivables and payables, net (a)																		-11
	401(h) account restricted for other
		postretirement benefit obligations					-115												-102
	Total PPL Services Corporation Master Trust
		pension assets				$	4,156											$	3,939
	(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	'
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2013 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period						$	1		$	27		$	75		$	42		$	1		$	146
		Actual return on plan assets
				Relating to assets still held
					at the reporting date									3			2						5
				Relating to assets sold during the period							5												5
		Purchases, sales and settlements									-9			2			-7						-14
		Transfers from level 3 to level 2																		-1			-1
	Balance at end of period						$	1		$	23		$	80		$	37		$			$	141
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2012 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period									$	7		$	45		$	46					$	98
		Actual return on plan assets
				Relating to assets still held
					at the reporting date						1			10			3						14
				Relating to assets sold during the period							2												2
		Purchases, sales and settlements					$	1			21			20			-7						35
		Transfers from level 2 to level 3																	$	1			1
		Transfers from level 3 to level 2									-4												-4
	Balance at end of period						$	1		$	27		$	75		$	42		$	1		$	146
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, 2013												December 31, 2012
									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					$	12		$	12								$	13		$	13
	U.S. Equity securities:
			Large-cap				182					$	182						145					$	145
			Commingled debt				100						100						119						119
	Debt securities:
			Municipalities				36						36						41						41
	Total VEBA trust assets, at fair value						330		$	12		$	318						318		$	13		$	305
	Receivables and payables, net (a)						1												1
	401(h) account assets (b)						115												102
	Total other postretirement benefit plan
		assets				$	446											$	421
	(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
	(b)       LKE's other postretirement benefit plan was invested primarily in a 401(h) account as disclosed in the PPL Services Corporation Master Trust.
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	'
	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by LKE.
						Other Postretirement
									Expected
						Benefit			Federal
				Pension		Payment			Subsidy
	2014		$	58		$	13		$	1
	2015			57			13
	2016			60			14			1
	2017			64			14
	2018			69			15			1
	2019-2023			425			81			2
Louisville Gas And Electric Co [Member]	'
Net Periodic Defined Benefit Costs (Credits) [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
					2013			2012			2011
	Net periodic defined benefit costs (credits):
	Service cost				$	2		$	2		$	2
	Interest cost					14			14			14
	Expected return on plan assets					-20			-19			-18
	Amortization of:
			Prior service cost (credit)			2			3			2
			Actuarial (gain) loss			14			11			11
	Net periodic defined benefit costs (credits)				$	12		$	11		$	11
	Other Changes in Plan Assets and Benefit Obligations
		Recognized in Regulatory Assets - Gross:
	Net (gain) loss				$	-20		$	18		$	15
	Prior service cost (credit)											9
	Amortization of:
			Prior service (cost) credit			-2			-2			-2
			Actuarial gain (loss)			-14			-11			-11
	Total recognized in regulatory assets/liabilities					-36			5			11
	Total recognized in net periodic defined benefit costs and regulatory assets				$	-24		$	16		$	22
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 2014 are as follows.
			Pension
			Benefits
	Prior service cost (credit)		$	2
	Actuarial (gain) loss			6
	Total		$	8
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	'
	In the table above, for PPL Energy Supply and LG&E, amounts include costs for the specific plans each sponsors and the following allocated costs of defined benefit plans sponsored by PPL Services (for PPL Energy Supply) and by LKE (for LG&E), based on their participation in those plans, which management believes are reasonable:
					Pension Benefits										Other Postretirement Benefits
						2013			2012			2011			2013			2012			2011
	PPL Energy Supply				$	38		$	31		$	23		$	5		$	5		$	6
	LG&E			5			5			7			4			5			5
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.
				Pension Benefits
				U.S.						U.K.						Other Postretirement Benefits
				2013			2012			2013			2012			2013			2012
	PPL
		Discount rate			5.12%			4.22%			4.41%			4.27%			4.91%			4.00%
		Rate of compensation increase			3.97%			3.98%			4.00%			4.00%			3.96%			3.97%
	PPL Energy Supply
		Discount rate			5.18%			4.25%									4.51%			3.77%
		Rate of compensation increase			3.94%			3.95%									3.94%			3.95%
	LKE
		Discount rate			5.18%			4.24%									4.91%			3.99%
		Rate of compensation increase			4.00%			4.00%									4.00%			4.00%
	LG&E
		Discount rate			5.13%			4.20%
	The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31.
				Pension Benefits
				U.S.									U.K.									Other Postretirement Benefits
				2013			2012			2011			2013			2012			2011			2013			2012			2011
	PPL
		Discount rate			4.22%			5.06%			5.42%			4.27%			5.24%			5.59%			4.00%			4.80%			5.14%
		Rate of compensation increase			3.98%			4.02%			4.88%			4.00%			4.00%			3.75%			3.97%			4.00%			4.90%
		Expected return on plan assets (a)			7.03%			7.07%			7.25%			7.16%			7.17%			7.04%			5.94%			5.99%			6.57%
	PPL Energy Supply
		Discount rate			4.25%			5.12%			5.47%												3.77%			4.60%			4.95%
		Rate of compensation increase			3.95%			4.00%			4.75%												3.95%			4.00%			4.75%
		Expected return on plan assets (a)			7.00%			7.00%			7.25%												N/A			N/A			N/A
	LKE
		Discount rate			4.24%			5.09%			5.49%												3.99%			4.78%			5.12%
		Rate of compensation increase			4.00%			4.00%			5.25%												4.00%			4.00%			5.25%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%												6.76%			7.02%			7.16%
	LG&E
		Discount rate			4.20%			5.00%			5.39%
		Expected return on plan assets (a)			7.10%			7.25%			7.25%
	(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.
						2013			2012			2011
	PPL and PPL Energy Supply
		Health care cost trend rate assumed for next year
				- obligations			7.60%			8.00%			8.50%
				- cost			8.00%			8.50%			9.00%
		Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
				- obligations			5.00%			5.50%			5.50%
				- cost			5.50%			5.50%			5.50%
		Year that the rate reaches the ultimate trend rate
				- obligations			2020			2019			2019
				- cost			2019			2019			2019
Schedule of Funded Status of Defined Benefit Plans	'
	(LG&E)
	The funded status of LG&E's plan at December 31, was as follows:
									Pension Benefits
									2013			2012
	Change in Benefit Obligation
	Benefit Obligation, beginning of period								$	331		$	298
			Service cost							2			1
			Interest cost							14			14
			Actuarial (gain) loss							-35			32
			Gross benefits paid (a)							-21			-14
	Benefit Obligation, end of period									291			331
	Change in Plan Assets
	Plan assets at fair value, beginning of period									287			256
			Actual return on plan assets							4			32
			Employer contributions							11			13
			Gross benefits paid (a)							-21			-14
	Plan assets at fair value, end of period									281			287
	Funded Status, end of period								$	-10		$	-44
	Amounts recognized in the Balance Sheets consist of:
			Noncurrent liability						$	-10		$	-44
	Net amount recognized, end of period								$	-10		$	-44
	Amounts recognized in regulatory assets (pre-tax)
		consist of:
	Prior service cost (credit)								$	15		$	17
	Net actuarial (gain) loss									90			123
	Total								$	105		$	140
	Total accumulated benefit obligation for defined benefit pension plan								$	288		$	328
	(a)       LG&E's pension plan offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The increase in gross benefits paid is primarily the result of $7 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with this offering.
	Allocations to LG&E resulted in liabilities at December 31 as follows:
			2013			2012
	Pension		$	9		$	58
	Other postretirement benefits			73			81
Schedules of Asset Allocation of U.S. Pension Trusts Assets	'
	The asset allocation for the trusts and the target allocation by portfolio, at December 31, are as follows:
										2013 Target Asset Allocation (a)
				Percentage of trust assets							Weighted
					2013 (a)			2012			Average			PPL Plans			LKE Plans
	Growth Portfolio				59%			58%			55%			55%			55%
		Equity securities			30%			31%
		Debt securities (b)			17%			18%
		Alternative investments			12%			9%
	Immunizing Portfolio				39%			41%			43%			43%			43%
		Debt securities (b)			40%			40%
		Derivatives			-1%			1%
	Liquidity Portfolio				2%			1%			2%			2%			2%
	Total				100%			100%			100%			100%			100%
	(a)       Allocations exclude consideration of cash for the WKE Bargaining Employees' Retirement Plan and a guaranteed 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 U.S. pension plan trusts by asset class and level within the fair value hierarchy was:
						December 31, 2013												December 31, 2012
									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					$	120		$	120								$	84		$	84
	Equity securities:
			U.S.:
				Large-cap			480			134		$	346						558			206		$	352
				Small-cap			137			137									124			124
				Commingled debt			749			13			736						676			56			620
			International				630			163			467						557			184			373
	Debt securities:
			U.S. Treasury and U.S. government sponsored
				agency			617			563			54						704			634			70
			Residential/commercial backed securities				12						11		$	1			12						11		$	1
			Corporate				963						940			23			874						847			27
			Other				24						24						24						23			1
			International				7						7						7						7
	Alternative investments:
			Commodities				108						108						59						59
			Real estate				134						134						93						93
			Private equity				80									80			75									75
			Hedge funds				210						210						125						125
	Derivatives:
			Interest rate swaps and swaptions				-49						-49						36						36
			Other				12						12						2						2
	Insurance contracts						37									37			42									42
	PPL Services Corporation Master Trust assets, at
		fair value					4,271		$	1,130		$	3,000		$	141			4,052		$	1,288		$	2,618		$	146
	Receivables and payables, net (a)																		-11
	401(h) account restricted for other
		postretirement benefit obligations					-115												-102
	Total PPL Services Corporation Master Trust
		pension assets				$	4,156											$	3,939
	(a)       Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	'
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2013 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period						$	1		$	27		$	75		$	42		$	1		$	146
		Actual return on plan assets
				Relating to assets still held
					at the reporting date									3			2						5
				Relating to assets sold during the period							5												5
		Purchases, sales and settlements									-9			2			-7						-14
		Transfers from level 3 to level 2																		-1			-1
	Balance at end of period						$	1		$	23		$	80		$	37		$			$	141
	A reconciliation of U.S. pension trust assets classified as Level 3 at December 31, 2012 is as follows:
							Residential/
							commercial
							backed			Corporate			Private			Insurance			Other
							securities			debt			equity			contracts			debt			Total
	Balance at beginning of period									$	7		$	45		$	46					$	98
		Actual return on plan assets
				Relating to assets still held
					at the reporting date						1			10			3						14
				Relating to assets sold during the period							2												2
		Purchases, sales and settlements					$	1			21			20			-7						35
		Transfers from level 2 to level 3																	$	1			1
		Transfers from level 3 to level 2									-4												-4
	Balance at end of period						$	1		$	27		$	75		$	42		$	1		$	146
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	'
	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plan.
				Pension
	2014		$	15
	2015			15
	2016			15
	2017			16
	2018			17
	2019-2023			99
Kentucky Utilities Co [Member]	'
Net Periodic Defined Benefit Costs (Credits) [Line Items]	'
Schedule of Funded Status of Defined Benefit Plans	'
	Allocations to KU resulted in liabilities at December 31 as follows.
			2013			2012
	Pension		$	11		$	104
	Other postretirement benefits			42			53

Jointly_Owned_Utility_Faciliti

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2013
Jointly Owned Facilities [Line Items]	'
Jointly Owned Utility Facilities	'
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
	KU
		31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
PPL Energy Supply LLC [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Utility Facilities	'
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
	KU
		31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
LG And E And KU Energy LLC [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Utility Facilities	'
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
	KU
		31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Louisville Gas And Electric Co [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Utility Facilities	'
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
	KU
		31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53
Kentucky Utilities Co [Member]	'
Jointly Owned Facilities [Line Items]	'
Jointly Owned Utility Facilities	'
	At December 31, 2013 and 2012, the Balance Sheets reflect the owned interests in the facilities listed below.
											Construction
				Ownership			Other		Accumulated		Work
				Interest	Electric Plant		Property		Depreciation		in Progress
	PPL
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
			Trimble County Units 1 & 2	75.00%		1,288				144		54
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
			Trimble County Units 1 & 2	75.00%		1,279				112		43
		Merrill Creek Reservoir		8.37%			$	22		15
	PPL Energy Supply
		December 31, 2013
		Generating Plants
			Susquehanna	90.00%	$	4,686			$	3,545	$	76
			Conemaugh	16.25%		247				131		63
			Keystone	12.34%		207				91		2
		Merrill Creek Reservoir		8.37%			$	22		16
		December 31, 2012
		Generating Plants
			Susquehanna	90.00%	$	4,628			$	3,530	$	65
			Conemaugh	16.25%		238				122		30
			Keystone	12.34%		206				82		3
		Merrill Creek Reservoir		8.37%			$	22		15
	LKE
		31-Dec-13
		Generating Plants
			Trimble County Unit 1	75.00%	$	308			$	42	$	18
			Trimble County Unit 2	75.00%		980				102		36
		31-Dec-12
		Generating Plants
			Trimble County Unit 1	75.00%	$	304			$	33	$	10
			Trimble County Unit 2	75.00%		975				79		33
	LG&E
		31-Dec-13
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	7	$	1
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				5		1
			Trimble County Unit 1	75.00%		308				42		18
			Trimble County Unit 2	14.25%		200				19		14
			Trimble County Units 5-6	29.00%		29				3
			Trimble County Units 7-10	37.00%		69				7		1
			Cane Run Unit 7	22.00%								91
			Green River Unit 5	40.00%								1
		31-Dec-12
		Generating Plants
			E.W. Brown Units 6-7	38.00%	$	40			$	5
			Paddy's Run Unit 13 & E.W. Brown Unit 5	53.00%		46				3
			Trimble County Unit 1	75.00%		304				33	$	10
			Trimble County Unit 2	14.25%		198				14		13
			Trimble County Units 5-6	29.00%		29				2
			Trimble County Units 7-10	37.00%		68				6		2
			Cane Run Unit 7	22.00%								16
	KU
		31-Dec-13
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	11	$	2
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				4		1
		Trimble County Unit 2	60.75%		780				83		22
		Trimble County Units 5-6	71.00%		70				8
		Trimble County Units 7-10	63.00%		118				12		2
		Cane Run Unit 7	78.00%								317
		Green River Unit 5	60.00%								2
	31-Dec-12
	Generating Plants
		E.W. Brown Units 6-7	62.00%	$	64			$	7	$	1
		Paddy's Run Unit 13 & E.W. Brown Unit 5	47.00%		42				2
		Trimble County Unit 2	60.75%		777				65		20
		Trimble County Units 5-6	71.00%		70				4
		Trimble County Units 7-10	63.00%		116				10		2
		Cane Run Unit 7	78.00%								53

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies [Line Items]	'
Unrecorded Unconditional Purchase Obligations	'
	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 as follows:
		LG&E			KU			Total
	2014	$	18		$	8		$	26
	2015		18			8			26
	2016		18			8			26
	2017		19			8			27
	2018		20			9			29
	Thereafter		504			224			728
		$	597		$	265		$	862
	In addition, LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows:
		2013			2012			2011
	LG&E	$	18		$	20		$	22
	KU		8			9			10
	Total	$	26		$	29		$	32
Labor Agreement Negotiations	'
	The labor agreements expiring in 2014 covered the following employees at December 31, 2013:
		Number of Employees		Percent of Total Workforce
	PPL	3,755		20%
	PPL Energy Supply	1,190		24%
	PPL Electric	1,419		63%
	LKE	774		22%
	LG&E	701		70%
	KU	73		7%
Guarantees	'
	The table below details guarantees provided as of December 31, 2013.
			Exposure at				Expiration
			December 31, 2013				Date
	PPL
	Indemnifications related to the WPD Midlands acquisition				(a)
	WPD indemnifications for entities in liquidation and sales of assets		$	12	(b)		2017 - 2018
	WPD guarantee of pension and other obligations of unconsolidated entities			127	(c)
	PPL Energy Supply
	Letters of credit issued on behalf of affiliates			29	(d)		2014 - 2015
	Indemnifications for sales of assets			250	(e)		2025
	Guarantee of a portion of a divested unconsolidated entity's debt			22	(f)		2018
	PPL Electric
	Guarantee of inventory value			27	(g)		2017
	LKE
	Indemnification of lease termination and other divestitures			301	(h)		2021 - 2023
	LG&E and KU
	LG&E and KU guarantee of shortfall related to OVEC				(i)
	(a)       Indemnifications related to certain liabilities, including a specific unresolved tax issue and those relating to properties and assets owned by the seller that were transferred to WPD Midlands in connection with the acquisition. A cross indemnity has been received from the seller on the tax issue. The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.
	(b)       Indemnification to the liquidators and certain others for existing liabilities or expenses or liabilities arising during the liquidation process. The indemnifications are limited to distributions made from the subsidiary to its parent either prior or subsequent to liquidation or is 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 electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At December 31, 2013, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.
	(d)       Standby letter of credit arrangements under PPL Energy Supply's credit facilities for the purposes of protecting various third parties against nonperformance by PPL. This is not a guarantee by PPL on a consolidated basis
	(e)       Indemnifications are governed by the specific sales agreement and include breach of the representations, warranties and covenants, and liabilities for certain other matters. PPL Energy Supply's maximum exposure with respect to certain indemnifications and the expiration of the indemnifications cannot be estimated because the maximum potential liability is not capped by the transaction documents and the expiration date is based on the applicable statute of limitations. The exposure and expiration date noted is based on those cases in which the agreements provide for specific limits.
	(f)       Relates to a guarantee of one-third of the divested entity's debt. The purchaser provided a cross-indemnity, secured by a lien on the purchaser's stock of the divested entity. The exposure noted reflects principal only.
	(g)       A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold.
	(h)       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 guarantees is the LKE guarantee covering operational, regulatory and environmental commitments 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 fall outside the cumulative cap. LKE has contested the applicability of the indemnification requirement relating to one matter presented by a counterparty under this guarantee. Another guarantee with a maximum exposure of $100 million covering other indemnifications expires in 2023. In May 2012, LKE's indemnitee received an arbitration panel's decision affecting this matter, which granted LKE's indemnitee certain rights of first refusal to purchase excess power at a market-based price rather than at an absolute fixed price. In January 2013, LKE's indemnitee commenced a proceeding in the Kentucky Court of Appeals appealing the December 2012 order of the Henderson Circuit Court, confirming the arbitration award. A decision in the appellate matter may occur during 2014. LKE believes its indemnification obligations in this matter remain subject to various uncertainties, including potential for additional legal challenges regarding the arbitration decision as well as future prices, availability and demand for the subject excess power. LKE continues to evaluate various legal and commercial options with respect to this indemnification matter. The ultimate outcomes of the WKE termination-related indemnifications cannot be predicted at this time. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum; however, LKE is not aware of formal claims under such indemnities made by any party at this time. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. In the second quarter of 2012, LKE adjusted its estimated liability for certain of these indemnifications by $9 million ($5 million after-tax), which is reflected in "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statement of Income. The adjustment was recorded in the Kentucky Regulated segment for PPL. LKE cannot predict the ultimate outcomes of such indemnification circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded.
	(i)       Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts currently included within a demand charge designed to cover these costs over the term of the contract. LKE's proportionate share of OVEC's outstanding debt was $129 million at December 31, 2013, consisting of LG&E's share of $89 million and KU's share of $40 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchases 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	'
	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 as follows:
		LG&E			KU			Total
	2014	$	18		$	8		$	26
	2015		18			8			26
	2016		18			8			26
	2017		19			8			27
	2018		20			9			29
	Thereafter		504			224			728
		$	597		$	265		$	862
	In addition, LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows:
		2013			2012			2011
	LG&E	$	18		$	20		$	22
	KU		8			9			10
	Total	$	26		$	29		$	32
Louisville Gas And Electric Co [Member]	'
Commitments and Contingencies [Line Items]	'
Unrecorded Unconditional Purchase Obligations	'
	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 as follows:
		LG&E			KU			Total
	2014	$	18		$	8		$	26
	2015		18			8			26
	2016		18			8			26
	2017		19			8			27
	2018		20			9			29
	Thereafter		504			224			728
		$	597		$	265		$	862
	In addition, LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows:
		2013			2012			2011
	LG&E	$	18		$	20		$	22
	KU		8			9			10
	Total	$	26		$	29		$	32
Kentucky Utilities Co [Member]	'
Commitments and Contingencies [Line Items]	'
Unrecorded Unconditional Purchase Obligations	'
	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 as follows:
		LG&E			KU			Total
	2014	$	18		$	8		$	26
	2015		18			8			26
	2016		18			8			26
	2017		19			8			27
	2018		20			9			29
	Thereafter		504			224			728
		$	597		$	265		$	862
	In addition, LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows:
		2013			2012			2011
	LG&E	$	18		$	20		$	22
	KU		8			9			10
	Total	$	26		$	29		$	32

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2013
PPL Energy Supply LLC [Member]	'
Related Party Transactions [Line Items]	'
Intercompany Support Cost Allocations	'
	PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
PPL Electric Utilities Corp [Member]	'
Related Party Transactions [Line Items]	'
Intercompany Support Cost Allocations	'
	PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
LG And E And KU Energy LLC [Member]	'
Related Party Transactions [Line Items]	'
Intercompany Support Cost Allocations	'
	PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
Louisville Gas And Electric Co [Member]	'
Related Party Transactions [Line Items]	'
Intercompany Support Cost Allocations	'
	PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204
Kentucky Utilities Co [Member]	'
Related Party Transactions [Line Items]	'
Intercompany Support Cost Allocations	'
	PPL Services and LKS charged the following amounts for the years ended December 31, and believe these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
			2013		2012			2011
	PPL Energy Supply from PPL Services	$	218	$	212		$	189
	PPL Electric from PPL Services		146		157			145
	LKE from PPL Services		15		15			16
	LG&E from LKS		216			186			190
	KU from LKS		207			161			204

Other_Income_Expense_net_Table

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2013
Other Income (Expense) - net [Line Items]	'
Other Income (Expense) - net	'
	17. Other Income (Expense) - net
	(All Registrants)
	The breakdown of "Other Income (Expense) - net" for the years ended December 31 was:
			PPL						PPL Energy Supply
			2013		2012		2011		2013		2012		2011
	Other Income
		Earnings on securities in NDT funds	$	23	$	22	$	24	$	23	$	22	$	24
		Interest income		3		5		7				1		1
		AFUDC - equity component		10		10		7
		Net hedge gains associated with the 2011 Bridge Facility (a)						55
		Earnings (losses) from equity method investments				-8		1
		Gain on redemption of debt (b)						22
		Miscellaneous - Domestic		18		11		10		14		5		6
		Miscellaneous - U.K.				2		1
		Total Other Income		54		42		127		37		28		31
	Other Expense
		Economic foreign currency exchange contracts (Note 19)		38		52		-10
		Charitable contributions		25		10		9		4		3		3
		WPD Midlands acquisition-related costs (Note 10)						34
		Foreign currency loss on 2011 Bridge Facility						57
		U.K. stamp duty tax (Note 10)						21
		Miscellaneous - Domestic		12		16		9		3		7		5
		Miscellaneous - U.K.		2		3		3
		Total Other Expense		77		81		123		7		10		8
	Other Income (Expense) - net		$	-23	$	-39	$	4	$	30	$	18	$	23
	(a)       Represents a gain on foreign currency contracts that hedged the repayment of the 2011 Bridge Facility borrowing.
	(b)       In July 2011, as a result of PPL Electric's redemption of 7.125% Senior Secured Bonds due 2013, PPL recorded a gain on the accelerated amortization of the fair value adjustment to the debt recorded in connection with previously settled fair value hedges.
PPL Energy Supply LLC [Member]	'
Other Income (Expense) - net [Line Items]	'
Other Income (Expense) - net	'
	17. Other Income (Expense) - net
	(All Registrants)
	The breakdown of "Other Income (Expense) - net" for the years ended December 31 was:
			PPL						PPL Energy Supply
			2013		2012		2011		2013		2012		2011
	Other Income
		Earnings on securities in NDT funds	$	23	$	22	$	24	$	23	$	22	$	24
		Interest income		3		5		7				1		1
		AFUDC - equity component		10		10		7
		Net hedge gains associated with the 2011 Bridge Facility (a)						55
		Earnings (losses) from equity method investments				-8		1
		Gain on redemption of debt (b)						22
		Miscellaneous - Domestic		18		11		10		14		5		6
		Miscellaneous - U.K.				2		1
		Total Other Income		54		42		127		37		28		31
	Other Expense
		Economic foreign currency exchange contracts (Note 19)		38		52		-10
		Charitable contributions		25		10		9		4		3		3
		WPD Midlands acquisition-related costs (Note 10)						34
		Foreign currency loss on 2011 Bridge Facility						57
		U.K. stamp duty tax (Note 10)						21
		Miscellaneous - Domestic		12		16		9		3		7		5
		Miscellaneous - U.K.		2		3		3
		Total Other Expense		77		81		123		7		10		8
	Other Income (Expense) - net		$	-23	$	-39	$	4	$	30	$	18	$	23
	(a)       Represents a gain on foreign currency contracts that hedged the repayment of the 2011 Bridge Facility borrowing.
	(b)       In July 2011, as a result of PPL Electric's redemption of 7.125% Senior Secured Bonds due 2013, PPL recorded a gain on the accelerated amortization of the fair value adjustment to the debt recorded in connection with previously settled fair value hedges.

Fair_Value_Measurements_and_Cr2

Fair Value Measurements and Credit Concentration (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements and Credit Concentration [Line Items]	'
Fair Value of Assets and Liabilities Measured on Recurring Basis	'
	The assets and liabilities measured at fair value were:
						December 31, 2013												December 31, 2012
						Total			Level 1			Level 2			Level 3			Total		Level 1		Level 2		Level 3
	PPL
	Assets
		Cash and cash equivalents				$	1,102		$	1,102								$	901	$	901
		Restricted cash and cash equivalents (a)					156			156									135		135
		Price risk management assets:
			Energy commodities				1,188			3		$	1,123		$	62			2,068		2	$	2,037	$	29
			Interest rate swaps				91						91						15				15
			Cross-currency swaps																14				13		1
		Total price risk management assets					1,279			3			1,214			62			2,097		2		2,065		30
		NDT funds:
			Cash and cash equivalents				14			14									11		11
			Equity securities
				U.S. large-cap			547			409			138						412		308		104
				U.S. mid/small-cap			81			33			48						60		25		35
			Debt securities
				U.S. Treasury			95			95									95		95
				U.S. government sponsored agency			6						6						9				9
				Municipality			77						77						82				82
				Investment-grade corporate			38						38						40				40
				Other			5						5						3				3
			Receivables (payables), net				1			-1			2								-2		2
		Total NDT funds					864			550			314						712		437		275
		Auction rate securities (b)					19									19			19				3		16
	Total assets					$	3,420		$	1,811		$	1,528		$	81		$	3,864	$	1,475	$	2,343	$	46
	Liabilities
		Price risk management liabilities:
			Energy commodities			$	1,070		$	4		$	1,028		$	38		$	1,566	$	2	$	1,557	$	7
			Interest rate swaps				36						36						80				80
			Foreign currency contracts				106						106						44				44
			Cross-currency swaps				32						32						4				4
		Total price risk management liabilities				$	1,244		$	4		$	1,202		$	38		$	1,694	$	2	$	1,685	$	7
	PPL Energy Supply
	Assets
		Cash and cash equivalents				$	239		$	239								$	413	$	413
		Restricted cash and cash equivalents (a)					85			85									63		63
		Price risk management assets:
			Energy commodities				1,188			3		$	1,123		$	62			2,068		2	$	2,037	$	29
		Total price risk management assets					1,188			3			1,123			62			2,068		2		2,037		29
		NDT funds:
			Cash and cash equivalents				14			14									11		11
			Equity securities
				U.S. large-cap			547			409			138						412		308		104
				U.S. mid/small-cap			81			33			48						60		25		35
			Debt securities
				U.S. Treasury			95			95									95		95
				U.S. government sponsored agency			6						6						9				9
				Municipality			77						77						82				82
				Investment-grade corporate			38						38						40				40
				Other			5						5						3				3
			Receivables (payables), net				1			-1			2								-2		2
		Total NDT funds					864			550			314						712		437		275
		Auction rate securities (b)					16									16			16				3		13
	Total assets					$	2,392		$	877		$	1,437		$	78		$	3,272	$	915	$	2,315	$	42
	Liabilities
		Price risk management liabilities:
			Energy commodities			$	1,070		$	4		$	1,028		$	38		$	1,566	$	2	$	1,557	$	7
		Total price risk management liabilities				$	1,070		$	4		$	1,028		$	38		$	1,566	$	2	$	1,557	$	7
	PPL Electric
	Assets
		Cash and cash equivalents				$	25		$	25								$	140	$	140
	Restricted cash and cash equivalents (c)					12			12									13		13
Total assets					$	37		$	37								$	153	$	153
LKE
Assets
	Cash and cash equivalents				$	35		$	35								$	43	$	43
	Restricted cash and cash equivalents (d)					22			22									32		32
	Price risk management assets:
		Interest rate swaps																14			$	14
	Total price risk management assets																	14				14
Total assets					$	57		$	57								$	89	$	75	$	14
Liabilities
	Price risk management liabilities:
		Interest rate swaps			$	36					$	36					$	58			$	58
	Total price risk management liabilities				$	36					$	36					$	58			$	58
LG&E
Assets
	Cash and cash equivalents				$	8		$	8								$	22	$	22
	Restricted cash and cash equivalents (d)					22			22									32		32
	Price risk management assets:
		Interest rate swaps																7			$	7
	Total price risk management assets																	7				7
Total assets					$	30		$	30								$	61	$	54	$	7
Liabilities
	Price risk management liabilities:
		Interest rate swaps			$	36					$	36					$	58			$	58
	Total price risk management liabilities				$	36					$	36					$	58			$	58
KU
Assets
	Cash and cash equivalents				$	21		$	21								$	21	$	21
	Price risk management assets:
		Interest rate swaps																7			$	7
	Total price risk management assets																	7				7
Total assets					$	21		$	21								$	28	$	21	$	7
(a)       Current portion is included in "Restricted cash and cash equivalents" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
(b)       Included in "Other investments" on the Balance Sheets.
(c)       Current portion is included in "Other current assets" and the long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
(d)       Included in "Other noncurrent assets" on the Balance Sheets.
Reconciliation of Net Assets and Liabilities Classified as Level 3	'
	A reconciliation of net assets and liabilities classified as Level 3 for the years ended December 31 is as follows:
							PPL
							Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
							Energy			Auction			Cross-
							Commodities,			Rate			Currency
							net			Securities			Swaps			Total
	2013
	Balance at beginning of period						$	22		$	16		$	1		$	39
			Total realized/unrealized gains (losses)
					Included in earnings			-5									-5
					Included in OCI (a)									1			1
			Sales					-2									-2
			Settlements					-3									-3
			Transfers into Level 3					10			3			3			16
			Transfers out of Level 3					2						-5			-3
	Balance at end of period						$	24		$	19		$			$	43
	2012
	Balance at beginning of period						$	13		$	24		$	4		$	41
			Total realized/unrealized gains (losses)
					Included in earnings			2						-1			1
					Included in OCI (a)			1						1			2
			Sales								-5						-5
			Settlements					-13									-13
			Transfers into Level 3					8									8
			Transfers out of Level 3					11			-3			-3			5
	Balance at end of period						$	22		$	16		$	1		$	39
	(a)       "Energy Commodities" and "Cross-Currency Swaps" are included in "Qualifying derivatives" and "Auction Rate Securities" are included in "Available-for-sale securities" on the Statements of Comprehensive Income.
Significant Unobservable Inputs Used in Fair Value Measurement of Assets and Liabilities Classified as Level 3	'
	The significant unobservable inputs used in and quantitative information about the fair value measurement of assets and liabilities classified as Level 3 are as follows:
				December 31, 2013
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average) (a)
	PPL
	Energy commodities
		Retail natural gas sales contracts (b)	$	36		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		10% - 100% (86%)
		Full-requirement sales contracts (c)		-12		Discounted cash flow		Proprietary model		100% (100%)
	Auction rate securities (f)			19		Discounted cash flow		Modeled from SIFMA Index		10% - 80% (63%)
	PPL Energy Supply
	Energy commodities
		Retail natural gas sales contracts (b)	$	36		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		10% - 100% (86%)
		Full-requirement sales contracts (c)		-12		Discounted cash flow		Proprietary model		100% (100%)
	Auction rate securities (f)			16		Discounted cash flow		Modeled from SIFMA Index		10% - 80% (63%)
				December 31, 2012
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average) (a)
	PPL
	Energy commodities
		Retail natural gas sales contracts (b)	$	24		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		21% - 100% (75%)
		Power sales contracts (d)		-4		Discounted cash flow		Proprietary model used to calculate forward basis prices		24% (24%)
		FTR purchase contracts (e)		2		Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
	Auction rate securities (f)			16		Discounted cash flow		Modeled from SIFMA Index		54% - 74% (64%)
	Cross-currency swaps (g)			1		Discounted cash flow		Credit valuation adjustment		22% (22%)
	PPL Energy Supply
	Energy commodities
		Retail natural gas sales contracts (b)	$	24		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		21% - 100% (75%)
		Power sales contracts (d)		-4		Discounted cash flow		Proprietary model used to calculate forward basis prices		24% (24%)
		FTR purchase contracts (e)		2		Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
	Auction rate securities (f)			13		Discounted cash flow		Modeled from SIFMA Index		57% - 74% (65%)
	(a)       For energy commodities and auction rate securities, the range and weighted average represent the percentage of fair value derived from the unobservable inputs. For cross-currency swaps, the range and weighted average represent the percentage decrease in fair value due to the unobservable inputs used in the model to calculate the credit valuation adjustment.
	(b)       As the forward price of natural gas increases/(decreases), the fair value of contracts (decreases)/increases.
	(c)       As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases. As the volumetric assumptions for full-requirement sales contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases). As the volumetric assumptions for full-requirement sales contracts in a loss position increase/(decrease), the fair value of contracts (decreases)/increases.
	(d)       As the forward price of basis increases/(decreases), the fair value of contracts (decreases)/increases.
	(e)       As the forward implied spread increases/(decreases), the fair value of contracts increases/(decreases).
	(f)       The model used to calculate fair value incorporates an assumption that the auctions will continue to fail. As the modeled forward rates of the SIFMA Index increase/(decrease), the fair value of the securities increases/(decreases).
	(g)       The credit valuation adjustment incorporates projected probabilities of default and estimated recovery rates. As the credit valuation adjustment increases/(decreases), the fair value of the swaps (decreases)/increases.
	The significant unobservable inputs used in and the quantitative information about the nonrecurring fair value measurement of assets and liabilities classified as Level 3 are as follows:
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average)
	PPL and PPL Energy Supply
	Corette plant and emission allowances:
		31-Dec-13		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
	PPL, LKE and KU
	Equity investment in EEI:
		31-Dec-12		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
Fair Value of Assets and Liabilities Classified as Level 3 Measured on Recurring Basis Included in Earnings	'
	Net gains and losses on assets and liabilities classified as Level 3 and included in earnings for the years ended December 31 were reported in the Statements of Income as follows:
																										Cross-Currency
					Energy Commodities, net																					Swaps
					Unregulated						Unregulated Retail											Energy				Interest
					Wholesale Energy						Energy								Fuel			Purchases				Expense
					2013			2012			2013				2012			2013		2012		2013		2012		2013	2012
	PPL
	Total gains (losses) included in earnings				$	-36		$	-19			$	25		$	26		$	3			$	3	$	-5		$	-1
	Change in unrealized gains (losses) relating to
		positions still held at the reporting date				-23			-3				24			29							1		1
	PPL Energy Supply
	Total gains (losses) included in earnings					-36			-19				25			26			3				3		-5
	Change in unrealized gains (losses) relating to
		positions still held at the reporting date				-23			-3				24			29							1		1
Fair Value of Assets and Liabilities Measured on Nonrecurring Basis	'
	The following nonrecurring fair value measurements occurred during the reporting periods, resulting in asset impairments.
					Carrying			Fair Value Measurements Using
					Amount (a)			Level 2			Level 3			Loss (b)
	PPL and PPL Energy Supply
		Corette plant and emission allowances:
			2013		$	65								$	65
		RECs (c):
			2011			6		$	1						5
	PPL, LKE and KU
		Equity investment in EEI:
			2012			25									25
	(a)       Represents carrying value before fair value measurement.
	(b)       The loss on the Corette plant and emission allowances was recorded in the Supply segment and included in "Other operation and maintenance" on the Statement of Income. The loss on the EEI investment was recorded in the Kentucky Regulated segment and included in "Other-Than-Temporary Impairments" on the Statement of Income. Losses on RECs were recorded in the Supply segment and included in "Other operation and maintenance" on the Statements of Income.
	(c)       Current and long-term RECs are included in "Other current assets" and "Other intangibles" in their respective areas on the Balance Sheets.
Fair Value of Financial Instruments Not Recorded at Fair Value - Other	'
	The carrying amounts of contract adjustment payments related to the Purchase Contract component of the Equity Units and long-term debt on the Balance Sheets and their estimated fair values are set forth below.
				December 31, 2013						December 31, 2012
				Carrying						Carrying
				Amount			Fair Value			Amount			Fair Value
	PPL
		Contract adjustment payments (a)		$	21		$	22		$	105		$	106
		Long-term debt			20,907			22,177			19,476			21,671
	PPL Energy Supply
		Long-term debt			2,525			2,658			3,272			3,556
	PPL Electric
		Long-term debt			2,315			2,483			1,967			2,333
	LKE
		Long-term debt			4,565			4,672			4,075			4,423
	LG&E
		Long-term debt			1,353			1,372			1,112			1,178
	KU
		Long-term debt			2,091			2,155			1,842			2,056
	(a)       Included in "Other current liabilities" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
PPL Energy Supply LLC [Member]	'
Fair Value Measurements and Credit Concentration [Line Items]	'
Reconciliation of Net Assets and Liabilities Classified as Level 3	'
	A reconciliation of net assets and liabilities classified as Level 3 for the years ended December 31 is as follows:
							PPL Energy Supply
							Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
							Energy			Auction
							Commodities,			Rate
							net			Securities			Total
	2013
	Balance at beginning of period						$	22		$	13		$	35
			Total realized/unrealized gains (losses)
					Included in earnings			-5						-5
			Sales					-2						-2
			Settlements					-3						-3
			Transfers into Level 3					10			3			13
			Transfers out of Level 3					2						2
	Balance at end of period						$	24		$	16		$	40
	2012
	Balance at beginning of period						$	13		$	19		$	32
			Total realized/unrealized gains (losses)
					Included in earnings			2						2
					Included in OCI (a)			1						1
			Sales								-3			-3
			Settlements					-13						-13
			Transfers into Level 3					8						8
			Transfers out of Level 3					11			-3			8
	Balance at end of period						$	22		$	13		$	35
	(a)       "Energy Commodities" are included in "Qualifying derivatives" and "Auction Rate Securities" are included in "Available-for-sale securities" on the Statements of Comprehensive Income.
Significant Unobservable Inputs Used in Fair Value Measurement of Assets and Liabilities Classified as Level 3	'
	The significant unobservable inputs used in and quantitative information about the fair value measurement of assets and liabilities classified as Level 3 are as follows:
				December 31, 2013
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average) (a)
	PPL
	Energy commodities
		Retail natural gas sales contracts (b)	$	36		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		10% - 100% (86%)
		Full-requirement sales contracts (c)		-12		Discounted cash flow		Proprietary model		100% (100%)
	Auction rate securities (f)			19		Discounted cash flow		Modeled from SIFMA Index		10% - 80% (63%)
	PPL Energy Supply
	Energy commodities
		Retail natural gas sales contracts (b)	$	36		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		10% - 100% (86%)
		Full-requirement sales contracts (c)		-12		Discounted cash flow		Proprietary model		100% (100%)
	Auction rate securities (f)			16		Discounted cash flow		Modeled from SIFMA Index		10% - 80% (63%)
				December 31, 2012
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average) (a)
	PPL
	Energy commodities
		Retail natural gas sales contracts (b)	$	24		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		21% - 100% (75%)
		Power sales contracts (d)		-4		Discounted cash flow		Proprietary model used to calculate forward basis prices		24% (24%)
		FTR purchase contracts (e)		2		Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
	Auction rate securities (f)			16		Discounted cash flow		Modeled from SIFMA Index		54% - 74% (64%)
	Cross-currency swaps (g)			1		Discounted cash flow		Credit valuation adjustment		22% (22%)
	PPL Energy Supply
	Energy commodities
		Retail natural gas sales contracts (b)	$	24		Discounted cash flow		Observable wholesale prices used as proxy for retail delivery points		21% - 100% (75%)
		Power sales contracts (d)		-4		Discounted cash flow		Proprietary model used to calculate forward basis prices		24% (24%)
		FTR purchase contracts (e)		2		Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
	Auction rate securities (f)			13		Discounted cash flow		Modeled from SIFMA Index		57% - 74% (65%)
	(a)       For energy commodities and auction rate securities, the range and weighted average represent the percentage of fair value derived from the unobservable inputs. For cross-currency swaps, the range and weighted average represent the percentage decrease in fair value due to the unobservable inputs used in the model to calculate the credit valuation adjustment.
	(b)       As the forward price of natural gas increases/(decreases), the fair value of contracts (decreases)/increases.
	(c)       As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases. As the volumetric assumptions for full-requirement sales contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases). As the volumetric assumptions for full-requirement sales contracts in a loss position increase/(decrease), the fair value of contracts (decreases)/increases.
	(d)       As the forward price of basis increases/(decreases), the fair value of contracts (decreases)/increases.
	(e)       As the forward implied spread increases/(decreases), the fair value of contracts increases/(decreases).
	(f)       The model used to calculate fair value incorporates an assumption that the auctions will continue to fail. As the modeled forward rates of the SIFMA Index increase/(decrease), the fair value of the securities increases/(decreases).
	(g)       The credit valuation adjustment incorporates projected probabilities of default and estimated recovery rates. As the credit valuation adjustment increases/(decreases), the fair value of the swaps (decreases)/increases.
	The significant unobservable inputs used in and the quantitative information about the nonrecurring fair value measurement of assets and liabilities classified as Level 3 are as follows:
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average)
	PPL and PPL Energy Supply
	Corette plant and emission allowances:
		31-Dec-13		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
	PPL, LKE and KU
	Equity investment in EEI:
		31-Dec-12		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
Fair Value of Assets and Liabilities Classified as Level 3 Measured on Recurring Basis Included in Earnings	'
	Net gains and losses on assets and liabilities classified as Level 3 and included in earnings for the years ended December 31 were reported in the Statements of Income as follows:
																										Cross-Currency
					Energy Commodities, net																					Swaps
					Unregulated						Unregulated Retail											Energy				Interest
					Wholesale Energy						Energy								Fuel			Purchases				Expense
					2013			2012			2013				2012			2013		2012		2013		2012		2013	2012
	PPL
	Total gains (losses) included in earnings				$	-36		$	-19			$	25		$	26		$	3			$	3	$	-5		$	-1
	Change in unrealized gains (losses) relating to
		positions still held at the reporting date				-23			-3				24			29							1		1
	PPL Energy Supply
	Total gains (losses) included in earnings					-36			-19				25			26			3				3		-5
	Change in unrealized gains (losses) relating to
		positions still held at the reporting date				-23			-3				24			29							1		1
Fair Value of Assets and Liabilities Measured on Nonrecurring Basis	'
	The following nonrecurring fair value measurements occurred during the reporting periods, resulting in asset impairments.
					Carrying			Fair Value Measurements Using
					Amount (a)			Level 2			Level 3			Loss (b)
	PPL and PPL Energy Supply
		Corette plant and emission allowances:
			2013		$	65								$	65
		RECs (c):
			2011			6		$	1						5
	PPL, LKE and KU
		Equity investment in EEI:
			2012			25									25
	(a)       Represents carrying value before fair value measurement.
	(b)       The loss on the Corette plant and emission allowances was recorded in the Supply segment and included in "Other operation and maintenance" on the Statement of Income. The loss on the EEI investment was recorded in the Kentucky Regulated segment and included in "Other-Than-Temporary Impairments" on the Statement of Income. Losses on RECs were recorded in the Supply segment and included in "Other operation and maintenance" on the Statements of Income.
	(c)       Current and long-term RECs are included in "Other current assets" and "Other intangibles" in their respective areas on the Balance Sheets.
LG And E And KU Energy LLC [Member]	'
Fair Value Measurements and Credit Concentration [Line Items]	'
Significant Unobservable Inputs Used in Fair Value Measurement of Assets and Liabilities Classified as Level 3	'
	The significant unobservable inputs used in and the quantitative information about the nonrecurring fair value measurement of assets and liabilities classified as Level 3 are as follows:
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average)
	PPL and PPL Energy Supply
	Corette plant and emission allowances:
		31-Dec-13		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
	PPL, LKE and KU
	Equity investment in EEI:
		31-Dec-12		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
Fair Value of Assets and Liabilities Measured on Nonrecurring Basis	'
	The following nonrecurring fair value measurements occurred during the reporting periods, resulting in asset impairments.
					Carrying			Fair Value Measurements Using
					Amount (a)			Level 2			Level 3			Loss (b)
	PPL and PPL Energy Supply
		Corette plant and emission allowances:
			2013		$	65								$	65
		RECs (c):
			2011			6		$	1						5
	PPL, LKE and KU
		Equity investment in EEI:
			2012			25									25
Kentucky Utilities Co [Member]	'
Fair Value Measurements and Credit Concentration [Line Items]	'
Significant Unobservable Inputs Used in Fair Value Measurement of Assets and Liabilities Classified as Level 3	'
	The significant unobservable inputs used in and the quantitative information about the nonrecurring fair value measurement of assets and liabilities classified as Level 3 are as follows:
				Fair Value, net				Significant		Range
				Asset		Valuation		Unobservable		(Weighted
				(Liability)		Technique		Input(s)		Average)
	PPL and PPL Energy Supply
	Corette plant and emission allowances:
		31-Dec-13		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
	PPL, LKE and KU
	Equity investment in EEI:
		31-Dec-12		$		Discounted cash flow		Long-term forward price curves and capital expenditure projections		100% (100%)
Fair Value of Assets and Liabilities Measured on Nonrecurring Basis	'
	The following nonrecurring fair value measurements occurred during the reporting periods, resulting in asset impairments.
					Carrying			Fair Value Measurements Using
					Amount (a)			Level 2			Level 3			Loss (b)
	PPL and PPL Energy Supply
		Corette plant and emission allowances:
			2013		$	65								$	65
		RECs (c):
			2011			6		$	1						5
	PPL, LKE and KU
		Equity investment in EEI:
			2012			25									25

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities [Line Items]	'
Commodity Price Risk (Non-trading) - Economic Activity - Pre-tax Gains (Losses) Associated with Economic Activity	'
	The unrealized gains (losses) for economic activity were as follows.
				2013			2012			2011
	Operating Revenues
		Unregulated wholesale energy		$	-721		$	-311		$	1,407
		Unregulated retail energy			12			-17			31
	Operating Expenses
		Fuel			-4			-14			6
		Energy purchases			586			442			-1,123
Commodity Volumes - Volumes of Derivative (Sales) Purchase Contracts	'
	At December 31, 2013, the net volumes of derivative (sales)/purchase contracts used in support of the various strategies discussed above were as follows.
					Volumes (a)
	Commodity		Unit of Measure		2014		2015		2016		Thereafter
	Power		MWh		-33,278,963		-14,421,817		4,348,927		18,931,370
	Capacity		MW-Month		-19,575		-3,929		501		9
	Gas		MMBtu		25,869,617		-33,082,289		19,082,945		-9,202,403
	Coal		Tons		495,900
	FTRs		MW-Month		9,581		1,705
	Oil		Barrels		150,000		380,869		274,137		101,261
	(a)       Volumes for option contracts factor in the probability of an option being exercised and may be less than the notional amount of the option.
Fair Value and Balance Sheet Location of Derivative Instruments	'
	The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets.
								December 31, 2013												December 31, 2012
								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)				$	82								$	4		$	14		$	22					$	5
				Cross-currency swaps							$	4												3
				Foreign currency
					contracts							16						55						2						23
				Commodity contracts										$	860			750			59					$	1,452			1,010
						Total current			82			20			860			809			73			27			1,452			1,038
	Noncurrent:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps (b)					9									32			1									53
				Cross-currency swaps								28									14			1
				Foreign currency
					contracts							4						31												19
				Commodity contracts											328			320			27						530			556
						Total noncurrent			9			32			328			383			42			1			530			628
	Total derivatives							$	91		$	52		$	1,188		$	1,192		$	115		$	28		$	1,982		$	1,666
	(a)       Represents the location on the Balance Sheets
	(b)       Excludes accrued interest, if applicable.
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	'
	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities.
		Derivatives in		Hedged Items in		Location of Gain
		Fair Value Hedging		Fair Value Hedging		(Loss) Recognized		Gain (Loss) Recognized			Gain (Loss) Recognized
		Relationships		Relationships		in Income		in Income on Derivative			in Income on Related Item
	2012
		Interest rate swaps		Fixed rate debt		Interest Expense					$	3
	2011
		Interest rate swaps		Fixed rate debt		Interest Expense		$	2			25
						Other Income (Expense) - net						22
														Gain (Loss) Recognized
														in Income on Derivative
						Derivative Gain					Gain (Loss) Reclassified			(Ineffective Portion and
				Derivative		(Loss) Recognized in			Location of Gain (Loss)		from AOCI into Income			Amount Excluded from
				Relationships		OCI (Effective Portion)			Recognized in Income		(Effective Portion)			Effectiveness Testing)
	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						Unregulated wholesale energy			263		$	1
									Energy purchases			-58
									Depreciation			2
									Other			3
		Total				$	86				$	163		$	1
		Net Investment Hedges:
			Foreign currency contracts			$	-14
	2012
		Cash Flow Hedges:
			Interest rate swaps			$	-28		Other income (Expense) - net		$	1
									Interest Expense			-18
			Cross-currency swaps				-15		Other Income (Expense) - net			-23
									Interest Expense			-2
			Commodity contracts				114		Unregulated wholesale energy			891		$	-1
									Energy purchases			-139			-2
									Depreciation			2
		Total				$	71				$	712		$	-3
		Net Investment Hedges:
			Foreign currency contracts			$	-7
	2011
		Cash Flow Hedges:
			Interest rate swaps			$	-55		Interest Expense		$	-13		$	-13
			Cross-currency swaps				-35		Other Income (Expense) - net			29
									Interest Expense			5
			Commodity contracts				431		Unregulated wholesale energy			835			-39
									Fuel			1
									Energy purchases			-243			1
									Depreciation			2
		Total				$	341				$	616		$	-51
		Net Investment Hedges:
			Foreign currency contracts			$	6
	Derivatives Not Designated as		Location of Gain (Loss) Recognized in
	Hedging Instruments		Income on Derivatives			2013			2012			2011
	Foreign currency contracts		Other Income (Expense) - net		$	-38		$	-52		$	65
	Interest rate swaps		Interest Expense			-8			-8			-8
	Commodity contracts		Utility									-1
			Unregulated wholesale energy			-85			1,199			1,600
			Unregulated retail energy			25			30			39
			Fuel			2						-1
			Energy purchases			130			-965			-1,493
			Total		$	26		$	204		$	201
	Derivatives Not Designated as		Location of Gain (Loss) Recognized as
	Hedging Instruments		Regulatory Liabilities/Assets			2013			2012			2011
	Interest rate swaps		Regulatory assets - noncurrent		$	22		$	1		$	-26
Derivatives Designated as		Location of Gain (Loss) Recognized as
Cash Flow Hedges		Regulatory Liabilities/Assets			2013			2012			2011
Interest rate swaps		Regulatory liabilities - noncurrent		$	72		$	14
Derivative Positions Eligible for Offset with Related Cash Collateral	'
	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
						Assets												Liabilities
									Eligible for Offset												Eligible for Offset
												Cash												Cash
									Derivative			Collateral									Derivative			Collateral
						Gross			Instruments			Received			Net			Gross			Instruments			Pledged			Net
	December 31, 2013
	PPL
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
		Treasury Derivatives					91			61						30			174			61			23			90
	Total					$	1,279		$	973		$	7		$	299		$	1,244		$	973		$	24		$	247
	PPL Energy Supply
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
	LKE
		Treasury Derivatives																$	36					$	20		$	16
	LG&E
		Treasury Derivatives																$	36					$	20		$	16
	December 31, 2012
	PPL
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
		Treasury Derivatives					29			19						10			128			19			30			79
	Total					$	2,097		$	1,432		$	111		$	554		$	1,694		$	1,432		$	39		$	223
	PPL Energy Supply
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
	LKE
		Treasury Derivatives				$	14								$	14		$	58					$	30		$	28
	LG&E
		Treasury Derivatives				$	7								$	7		$	58					$	30		$	28
	KU
		Treasury Derivatives				$	7								$	7
Credit Risk-Related Contingent Features	'
	At December 31, 2013, the effect of a decrease in credit ratings below investment grade on derivative contracts that contain credit risk-related contingent features and were in a net liability position is summarized as follows:
								PPL
					PPL			Energy Supply			LKE			LG&E
	Aggregate fair value of derivative instruments in a net liability
		position with credit risk-related contingent features			$	245		$	157		$	26		$	26
	Aggregate fair value of collateral posted on these derivative instruments					41			19			22			22
	Aggregate fair value of additional collateral requirements in the event of
		a credit downgrade below investment grade (a)				214			147			6			6
	(a)       Includes the effect of net receivables and payables already recorded on the Balance Sheet.
PPL Energy Supply LLC [Member]	'
Derivative Instruments and Hedging Activities [Line Items]	'
Commodity Price Risk (Non-trading) - Economic Activity - Pre-tax Gains (Losses) Associated with Economic Activity	'
	The unrealized gains (losses) for economic activity were as follows.
				2013			2012			2011
	Operating Revenues
		Unregulated wholesale energy		$	-721		$	-311		$	1,407
		Unregulated retail energy			12			-17			31
	Operating Expenses
		Fuel			-4			-14			6
		Energy purchases			586			442			-1,123
Commodity Volumes - Volumes of Derivative (Sales) Purchase Contracts	'
	At December 31, 2013, the net volumes of derivative (sales)/purchase contracts used in support of the various strategies discussed above were as follows.
					Volumes (a)
	Commodity		Unit of Measure		2014		2015		2016		Thereafter
	Power		MWh		-33,278,963		-14,421,817		4,348,927		18,931,370
	Capacity		MW-Month		-19,575		-3,929		501		9
	Gas		MMBtu		25,869,617		-33,082,289		19,082,945		-9,202,403
	Coal		Tons		495,900
	FTRs		MW-Month		9,581		1,705
	Oil		Barrels		150,000		380,869		274,137		101,261
	(a)       Volumes for option contracts factor in the probability of an option being exercised and may be less than the notional amount of the option.
Fair Value and Balance Sheet Location of Derivative Instruments	'
	The following tables present the fair value and location of derivative instruments recorded on the Balance Sheets.
								December 31, 2013												December 31, 2012
								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):
				Commodity contracts										$	860		$	750		$	59					$	1,452		$	1,010
						Total current									860			750			59						1,452			1,010
	Noncurrent:
		Price Risk Management
			Assets/Liabilities (a):
				Commodity contracts											328			320			27						530			556
						Total noncurrent									328			320			27						530			556
	Total derivatives													$	1,188		$	1,070		$	86					$	1,982		$	1,566
	(a)       Represents the location on the Balance Sheet.
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 or OCI. There were no gains (losses) on interest rate swaps for 2013 or 2012.
		Derivatives in		Hedged Items in		Location of Gain
		Fair Value Hedging		Fair Value Hedging		(Loss) Recognized		Gain (Loss) Recognized			Gain (Loss) Recognized
		Relationships		Relationships		in Income		in Income on Derivative			in Income on Related Item
	2011
		Interest rate swaps		Fixed rate debt		Interest Expense					$	2
														Gain (Loss) Recognized
														in Income on Derivative
						Derivative Gain					Gain (Loss) Reclassified			(Ineffective Portion and
				Derivative		(Loss) Recognized in			Location of Gain (Loss)		from AOCI into Income			Amount Excluded from
				Relationships		OCI (Effective Portion)			Recognized in Income		(Effective Portion)			Effectiveness Testing)
	2013
		Cash Flow Hedges:
			Commodity contracts						Unregulated wholesale energy		$	263		$	1
									Depreciation			2
									Energy purchases			-58
		Total									$	207		$	1
	2012
		Cash Flow Hedges:
			Commodity contracts			$	114		Unregulated wholesale energy		$	891		$	-1
									Depreciation			2
									Energy purchases			-139			-2
		Total				$	114				$	754		$	-3
	2011
		Cash Flow Hedges:
			Commodity contracts			$	431		Unregulated wholesale energy		$	835		$	-39
									Fuel			1
									Energy purchases			-243			1
									Depreciation			2
		Total				$	431				$	595		$	-38
	Derivatives Not Designated as		Location of Gain (Loss) Recognized in
	Hedging Instruments		Income on Derivatives			2013			2012			2011
	Commodity contracts		Unregulated wholesale energy		$	-85		$	1,199		$	1,600
			Unregulated retail energy			25			30			39
			Fuel			2						-1
			Energy purchases			130			-965			-1,493
			Total		$	72		$	264		$	145
Derivative Positions Eligible for Offset with Related Cash Collateral	'
	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
						Assets												Liabilities
									Eligible for Offset												Eligible for Offset
												Cash												Cash
									Derivative			Collateral									Derivative			Collateral
						Gross			Instruments			Received			Net			Gross			Instruments			Pledged			Net
	December 31, 2013
	PPL
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
		Treasury Derivatives					91			61						30			174			61			23			90
	Total					$	1,279		$	973		$	7		$	299		$	1,244		$	973		$	24		$	247
	PPL Energy Supply
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
	LKE
		Treasury Derivatives																$	36					$	20		$	16
	LG&E
		Treasury Derivatives																$	36					$	20		$	16
	December 31, 2012
	PPL
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
		Treasury Derivatives					29			19						10			128			19			30			79
	Total					$	2,097		$	1,432		$	111		$	554		$	1,694		$	1,432		$	39		$	223
	PPL Energy Supply
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
	LKE
		Treasury Derivatives				$	14								$	14		$	58					$	30		$	28
	LG&E
		Treasury Derivatives				$	7								$	7		$	58					$	30		$	28
	KU
		Treasury Derivatives				$	7								$	7
Credit Risk-Related Contingent Features	'
	At December 31, 2013, the effect of a decrease in credit ratings below investment grade on derivative contracts that contain credit risk-related contingent features and were in a net liability position is summarized as follows:
								PPL
					PPL			Energy Supply			LKE			LG&E
	Aggregate fair value of derivative instruments in a net liability
		position with credit risk-related contingent features			$	245		$	157		$	26		$	26
	Aggregate fair value of collateral posted on these derivative instruments					41			19			22			22
	Aggregate fair value of additional collateral requirements in the event of
		a credit downgrade below investment grade (a)				214			147			6			6
	(a)       Includes the effect of net receivables and payables already recorded on the Balance Sheet.
LG And E And KU Energy LLC [Member]	'
Derivative Instruments and Hedging Activities [Line Items]	'
Fair Value and Balance Sheet Location of Derivative Instruments	'
	The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges.
								December 31, 2013							December 31, 2012
								Assets			Liabilities				Assets			Liabilities
	Current:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps											$	14
	(a)       Represents the location on the Balance Sheet.
	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.
								December 31, 2013						December 31, 2012
								Assets			Liabilities				Assets			Liabilities
	Current:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps							$	4						$	5
						Total current						4							5
	Noncurrent:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps								32							53
						Total noncurrent						32							53
	Total derivatives										$	36						$	58
	(a)       Represents the location on the Balance Sheets.
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	'
	The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory liabilities.
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Regulatory liabilities - noncurrent		$	72		$	14
	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets.
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Interest Expense		$	-8		$	-8		$	-8
	Commodity contracts		Operating Revenues									-1
			Total		$	-8		$	-8		$	-9
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Regulatory assets - noncurrent		$	22		$	1		$	-26
Derivative Positions Eligible for Offset with Related Cash Collateral	'
	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
						Assets												Liabilities
									Eligible for Offset												Eligible for Offset
												Cash												Cash
									Derivative			Collateral									Derivative			Collateral
						Gross			Instruments			Received			Net			Gross			Instruments			Pledged			Net
	December 31, 2013
	PPL
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
		Treasury Derivatives					91			61						30			174			61			23			90
	Total					$	1,279		$	973		$	7		$	299		$	1,244		$	973		$	24		$	247
	PPL Energy Supply
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
	LKE
		Treasury Derivatives																$	36					$	20		$	16
	LG&E
		Treasury Derivatives																$	36					$	20		$	16
	December 31, 2012
	PPL
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
		Treasury Derivatives					29			19						10			128			19			30			79
	Total					$	2,097		$	1,432		$	111		$	554		$	1,694		$	1,432		$	39		$	223
	PPL Energy Supply
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
	LKE
		Treasury Derivatives				$	14								$	14		$	58					$	30		$	28
	LG&E
		Treasury Derivatives				$	7								$	7		$	58					$	30		$	28
	KU
		Treasury Derivatives				$	7								$	7
Credit Risk-Related Contingent Features	'
	At December 31, 2013, the effect of a decrease in credit ratings below investment grade on derivative contracts that contain credit risk-related contingent features and were in a net liability position is summarized as follows:
								PPL
					PPL			Energy Supply			LKE			LG&E
	Aggregate fair value of derivative instruments in a net liability
		position with credit risk-related contingent features			$	245		$	157		$	26		$	26
	Aggregate fair value of collateral posted on these derivative instruments					41			19			22			22
	Aggregate fair value of additional collateral requirements in the event of
		a credit downgrade below investment grade (a)				214			147			6			6
	(a)       Includes the effect of net receivables and payables already recorded on the Balance Sheet.
Louisville Gas And Electric Co [Member]	'
Derivative Instruments and Hedging Activities [Line Items]	'
Fair Value and Balance Sheet Location of Derivative Instruments	'
	The following table presents the fair value and the location on the Balance Sheets of derivative instruments designated as cash flow hedges.
								December 31, 2013							December 31, 2012
								Assets			Liabilities				Assets			Liabilities
	Current:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps											$	7
	(a)       Represents the location on the balance sheet.
	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.
								December 31, 2013						December 31, 2012
								Assets			Liabilities				Assets			Liabilities
	Current:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps							$	4						$	5
						Total current						4							5
	Noncurrent:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps								32							53
						Total noncurrent						32							53
	Total derivatives										$	36						$	58
	(a)       Represents the location on the Balance Sheets.
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	'
	The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory liabilities.
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Regulatory liabilities - noncurrent		$	36		$	7
	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets.
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Interest Expense		$	-8		$	-8		$	-8
	Commodity contracts		Operating Revenues									-1
			Total		$	-8		$	-8		$	-9
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Regulatory assets - noncurrent		$	22		$	1		$	-26
Derivative Positions Eligible for Offset with Related Cash Collateral	'
	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
						Assets												Liabilities
									Eligible for Offset												Eligible for Offset
												Cash												Cash
									Derivative			Collateral									Derivative			Collateral
						Gross			Instruments			Received			Net			Gross			Instruments			Pledged			Net
	December 31, 2013
	PPL
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
		Treasury Derivatives					91			61						30			174			61			23			90
	Total					$	1,279		$	973		$	7		$	299		$	1,244		$	973		$	24		$	247
	PPL Energy Supply
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
	LKE
		Treasury Derivatives																$	36					$	20		$	16
	LG&E
		Treasury Derivatives																$	36					$	20		$	16
	December 31, 2012
	PPL
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
		Treasury Derivatives					29			19						10			128			19			30			79
	Total					$	2,097		$	1,432		$	111		$	554		$	1,694		$	1,432		$	39		$	223
	PPL Energy Supply
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
	LKE
		Treasury Derivatives				$	14								$	14		$	58					$	30		$	28
	LG&E
		Treasury Derivatives				$	7								$	7		$	58					$	30		$	28
	KU
		Treasury Derivatives				$	7								$	7
Credit Risk-Related Contingent Features	'
	At December 31, 2013, the effect of a decrease in credit ratings below investment grade on derivative contracts that contain credit risk-related contingent features and were in a net liability position is summarized as follows:
								PPL
					PPL			Energy Supply			LKE			LG&E
	Aggregate fair value of derivative instruments in a net liability
		position with credit risk-related contingent features			$	245		$	157		$	26		$	26
	Aggregate fair value of collateral posted on these derivative instruments					41			19			22			22
	Aggregate fair value of additional collateral requirements in the event of
		a credit downgrade below investment grade (a)				214			147			6			6
	(a)       Includes the effect of net receivables and payables already recorded on the Balance Sheet.
Kentucky Utilities Co [Member]	'
Derivative Instruments and Hedging Activities [Line Items]	'
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, 2013							December 31, 2012
								Assets			Liabilities				Assets			Liabilities
	Current:
		Price Risk Management
			Assets/Liabilities (a):
				Interest rate swaps											$	7
	(a)       Represents the location on the Balance Sheets
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	'
	Derivative Instruments		Location of Gain (Loss)		2013			2012			2011
	Interest rate swaps		Regulatory liabilities - noncurrent		$	36		$	7
Derivative Positions Eligible for Offset with Related Cash Collateral	'
	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
						Assets												Liabilities
									Eligible for Offset												Eligible for Offset
												Cash												Cash
									Derivative			Collateral									Derivative			Collateral
						Gross			Instruments			Received			Net			Gross			Instruments			Pledged			Net
	December 31, 2013
	PPL
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
		Treasury Derivatives					91			61						30			174			61			23			90
	Total					$	1,279		$	973		$	7		$	299		$	1,244		$	973		$	24		$	247
	PPL Energy Supply
		Energy Commodities				$	1,188		$	912		$	7		$	269		$	1,070		$	912		$	1		$	157
	LKE
		Treasury Derivatives																$	36					$	20		$	16
	LG&E
		Treasury Derivatives																$	36					$	20		$	16
	December 31, 2012
	PPL
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
		Treasury Derivatives					29			19						10			128			19			30			79
	Total					$	2,097		$	1,432		$	111		$	554		$	1,694		$	1,432		$	39		$	223
	PPL Energy Supply
		Energy Commodities				$	2,068		$	1,413		$	111		$	544		$	1,566		$	1,413		$	9		$	144
	LKE
		Treasury Derivatives				$	14								$	14		$	58					$	30		$	28
	LG&E
		Treasury Derivatives				$	7								$	7		$	58					$	30		$	28
	KU
		Treasury Derivatives				$	7								$	7

Goodwill_and_Other_Intangible_1

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Other Intangible Assets [Abstract]	'
Goodwill Rollforward	'
	20. Goodwill and Other Intangible Assets
	Goodwill
	(PPL)
	The changes in the carrying amount of goodwill by segment were:
						U.K. Regulated						Kentucky Regulated					Supply				Total
						2013			2012			2013			2012		2013		2012		2013		2012
	PPL
	Balance at beginning of period (a)					$	3,076		$	3,032		$	662		$	662	$	420	$	420	$	4,158	$	4,114
		Changes during the period (b)					67			44												67		44
	Balance at end of period (a)					$	3,143		$	3,076		$	662		$	662	$	420	$	420	$	4,225	$	4,158
	(a)       There were no accumulated impairment losses related to goodwill.
	(b)       Primarily the effect of foreign currency exchange rates.
Other Intangible Assets	'
	Other Intangible Assets
	(PPL)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Contracts (a)			$	408		$	202		$	408		$	150
		Land and transmission rights				331			117			284			113
		Emission allowances/RECs (b)				16						17
		Licenses and other (c)				305			45			287			39
	Total subject to amortization					1,060			364			996			302
	Not subject to amortization due to indefinite life:
		Land and transmission rights				16						18
		Easements (d)				239						220
	Total not subject to amortization due to indefinite life					255						238
	Total				$	1,315		$	364		$	1,234		$	302
	(a)       Gross carrying amount includes the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition of LKE 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. 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)       "Other" includes costs for the development of licenses, the most significant of which is the COLA. Amortization of these costs begins when the related asset is placed in service. See Note 8 for additional information on the COLA.
	(d)       Gross carrying amount includes $88 million, which represents the fair value at the acquisition date of easements recognized as a result of the 2011 acquisition of WPD Midlands. See Note 10 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	'
	Amortization expense for the years ended December 31, excluding consumption of emission allowances/RECs of $23 million, $12 million, and $16 million in 2013, 2012 and 2011, was as follows:
				2013			2012			2011
	Intangible assets with no regulatory offset		$	10		$	14		$	25
	Intangible assets with regulatory offset			51			47			87
	Total		$	61		$	61		$	112
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:
				2014			2015			2016			2017			2018
	Intangible assets with no regulatory offset		$	10		$	10		$	8		$	8		$	8
	Intangible assets with regulatory offset			48			50			27			9			9
	Total		$	58		$	60		$	35		$	17		$	17
PPL Energy Supply LLC [Member]	'
Goodwill and Other Intangible Assets [Abstract]	'
Other Intangible Assets	'
	(PPL Energy Supply)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Land and transmission rights			$	17		$	14		$	17		$	13
		Emission allowances/RECs (a)				11						13
		Licenses and other (b)				295			39			277			35
	Total subject to amortization				$	323		$	53		$	307		$	48
	(a)       Emission allowances/RECs are expensed when consumed or sold; therefore, there is no accumulated amortization.
	(b)       "Other" includes costs for the development of licenses, the most significant of which is the COLA. Amortization of these costs begins when the related asset is placed in service. See Note 8 for additional information on the COLA.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	'
	Amortization expense for the years ended December 31, excluding consumption of emission allowances/RECs of $23 million, $12 million, and $16 million in 2013, 2012, and 2011 was as follows:
				2013			2012			2011
	Amortization expense		$	5		$	9		$	20
PPL Electric Utilities Corp [Member]	'
Goodwill and Other Intangible Assets [Abstract]	'
Other Intangible Assets	'
	(PPL Electric)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Land and transmission rights			$	293		$	102		$	249		$	99
		Licenses and other				5			1			4			1
	Total subject to amortization					298			103			253			100
	Not subject to amortization due to indefinite life:
		Land and transmission rights				16						18
	Total				$	314		$	103		$	271		$	100
LG And E And KU Energy LLC [Member]	'
Goodwill and Other Intangible Assets [Abstract]	'
Other Intangible Assets	'
	(LKE)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Coal contracts (a)			$	269		$	171		$	269		$	128
		Land and transmission rights				20			2			18			1
		Emission allowances (b)				4						4
		OVEC power purchase agreement (c)				126			25			126			17
	Total subject to amortization				$	419		$	198		$	417		$	146
	(a)       Gross carrying amount represents 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)       Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
	(c)       Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. See Note 6 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	'
	Amortization expense, excluding consumption of emission allowances, was as follows:
				2013			2012			2011
	Intangible assets with no regulatory offset		$	1					$	1
	Intangible assets with regulatory offset			51		$	47			87
	Total		$	52		$	47		$	88
Future Amortization Expense	'
	Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be:
				2014			2015			2016			2017			2018
	Intangible assets with regulatory offset		$	48		$	50		$	27		$	9		$	9
Louisville Gas And Electric Co [Member]	'
Goodwill and Other Intangible Assets [Abstract]	'
Other Intangible Assets	'
	(LG&E)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Coal contracts (a)			$	124		$	81		$	124		$	62
		Land and transmission rights				7			1			8			1
		Emission allowances (b)				1						1
		OVEC power purchase agreement (c)				87			17			87			13
	Total subject to amortization				$	219		$	99		$	220		$	76
	(a)       Gross carrying amount represents 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)       Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
	(c)       Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. See Note 6 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	'
	Amortization expense, excluding consumption of emission allowances, was as follows:
				2013			2012			2011
	Intangible assets with no regulatory offset								$	1
	Intangible assets with regulatory offset		$	23		$	23			45
	Total		$	23		$	23		$	46
Future Amortization Expense	'
	Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be:
				2014			2015			2016			2017			2018
	Intangible assets with regulatory offset		$	23		$	24		$	13		$	6		$	6
Kentucky Utilities Co [Member]	'
Goodwill and Other Intangible Assets [Abstract]	'
Other Intangible Assets	'
	(KU)
	The gross carrying amount and the accumulated amortization of other intangible assets were:
					December 31, 2013						December 31, 2012
					Gross						Gross
					Carrying			Accumulated			Carrying			Accumulated
					Amount			Amortization			Amount			Amortization
	Subject to amortization:
		Coal contracts (a)			$	145		$	90		$	145		$	66
		Land and transmission rights				13			1			10
		Emission allowances (b)				3						3
		OVEC power purchase agreement (c)				39			8			39			4
	Total subject to amortization				$	200		$	99		$	197		$	70
	(a)       Gross carrying amount represents 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)       Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
	(c)       Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. See Note 6 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	'
	Amortization expense, excluding consumption of emission allowances, was as follows:
				2013			2012			2011
	Intangible assets with no regulatory offset		$	1
	Intangible assets with regulatory offset			28		$	24		$	42
Future Amortization Expense	'
	Amortization expense for each of the next five years, excluding consumption of emission allowances, is estimated to be:
				2014			2015			2016			2017			2018
	Intangible assets with regulatory offset		$	24		$	26		$	13		$	3		$	3

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations [Line Items]	'
Asset Retirement Obligation Roll Forward	'
	The changes in the carrying amounts of AROs were as follows.
				PPL				PPL Energy Supply
				2013		2012		2013		2012
	ARO at beginning of period			$	552	$	497	$	375	$	359
		Accretion expense			38		36		29		28
		Obligations incurred			6		9		6		3
		Changes in estimated cash flow or settlement date			123		31		1		-7
		Effect of foreign currency exchange rates			1		1
		Obligations settled			-15		-22		-7		-8
	ARO at end of period			$	705	$	552	$	404	$	375
				LKE				LG&E				KU
				2013		2012		2013		2012		2013		2012
	ARO at beginning of period			$	131	$	118	$	62	$	57	$	69	$	61
		Accretion expense			7		6		3		3		4		3
		Obligations incurred					6								6
		Changes in estimated cash flow
			or settlement date		122		15		17		5		105		10
		Obligations settled			-8		-14		-8		-3				-11
	ARO at end of period			$	252	$	131	$	74	$	62	$	178	$	69
PPL Energy Supply LLC [Member]	'
Asset Retirement Obligations [Line Items]	'
Asset Retirement Obligation Roll Forward	'
	The changes in the carrying amounts of AROs were as follows.
				PPL				PPL Energy Supply
				2013		2012		2013		2012
	ARO at beginning of period			$	552	$	497	$	375	$	359
		Accretion expense			38		36		29		28
		Obligations incurred			6		9		6		3
		Changes in estimated cash flow or settlement date			123		31		1		-7
		Effect of foreign currency exchange rates			1		1
		Obligations settled			-15		-22		-7		-8
	ARO at end of period			$	705	$	552	$	404	$	375
				LKE				LG&E				KU
				2013		2012		2013		2012		2013		2012
	ARO at beginning of period			$	131	$	118	$	62	$	57	$	69	$	61
		Accretion expense			7		6		3		3		4		3
		Obligations incurred					6								6
		Changes in estimated cash flow
			or settlement date		122		15		17		5		105		10
		Obligations settled			-8		-14		-8		-3				-11
	ARO at end of period			$	252	$	131	$	74	$	62	$	178	$	69
LG And E And KU Energy LLC [Member]	'
Asset Retirement Obligations [Line Items]	'
Asset Retirement Obligation Roll Forward	'
	The changes in the carrying amounts of AROs were as follows.
				PPL				PPL Energy Supply
				2013		2012		2013		2012
	ARO at beginning of period			$	552	$	497	$	375	$	359
		Accretion expense			38		36		29		28
		Obligations incurred			6		9		6		3
		Changes in estimated cash flow or settlement date			123		31		1		-7
		Effect of foreign currency exchange rates			1		1
		Obligations settled			-15		-22		-7		-8
	ARO at end of period			$	705	$	552	$	404	$	375
				LKE				LG&E				KU
				2013		2012		2013		2012		2013		2012
	ARO at beginning of period			$	131	$	118	$	62	$	57	$	69	$	61
		Accretion expense			7		6		3		3		4		3
		Obligations incurred					6								6
		Changes in estimated cash flow
			or settlement date		122		15		17		5		105		10
		Obligations settled			-8		-14		-8		-3				-11
	ARO at end of period			$	252	$	131	$	74	$	62	$	178	$	69
Louisville Gas And Electric Co [Member]	'
Asset Retirement Obligations [Line Items]	'
Asset Retirement Obligation Roll Forward	'
	The changes in the carrying amounts of AROs were as follows.
				PPL				PPL Energy Supply
				2013		2012		2013		2012
	ARO at beginning of period			$	552	$	497	$	375	$	359
		Accretion expense			38		36		29		28
		Obligations incurred			6		9		6		3
		Changes in estimated cash flow or settlement date			123		31		1		-7
		Effect of foreign currency exchange rates			1		1
		Obligations settled			-15		-22		-7		-8
	ARO at end of period			$	705	$	552	$	404	$	375
				LKE				LG&E				KU
				2013		2012		2013		2012		2013		2012
	ARO at beginning of period			$	131	$	118	$	62	$	57	$	69	$	61
		Accretion expense			7		6		3		3		4		3
		Obligations incurred					6								6
		Changes in estimated cash flow
			or settlement date		122		15		17		5		105		10
		Obligations settled			-8		-14		-8		-3				-11
	ARO at end of period			$	252	$	131	$	74	$	62	$	178	$	69
Kentucky Utilities Co [Member]	'
Asset Retirement Obligations [Line Items]	'
Asset Retirement Obligation Roll Forward	'
	The changes in the carrying amounts of AROs were as follows.
				PPL				PPL Energy Supply
				2013		2012		2013		2012
	ARO at beginning of period			$	552	$	497	$	375	$	359
		Accretion expense			38		36		29		28
		Obligations incurred			6		9		6		3
		Changes in estimated cash flow or settlement date			123		31		1		-7
		Effect of foreign currency exchange rates			1		1
		Obligations settled			-15		-22		-7		-8
	ARO at end of period			$	705	$	552	$	404	$	375
				LKE				LG&E				KU
				2013		2012		2013		2012		2013		2012
	ARO at beginning of period			$	131	$	118	$	62	$	57	$	69	$	61
		Accretion expense			7		6		3		3		4		3
		Obligations incurred					6								6
		Changes in estimated cash flow
			or settlement date		122		15		17		5		105		10
		Obligations settled			-8		-14		-8		-3				-11
	ARO at end of period			$	252	$	131	$	74	$	62	$	178	$	69

AvailableforSale_Securities_Ta

Available-for-Sale Securities (Tables)	12 Months Ended
	Dec. 31, 2013
Available-for-Sale Securities [Line Items]	'
Available-for-Sale Securities	'
	The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of available-for-sale securities.
							December 31, 2013											December 31, 2012
										Gross			Gross							Gross		Gross
							Amortized			Unrealized			Unrealized					Amortized		Unrealized		Unrealized
							Cost			Gains			Losses			Fair Value		Cost		Gains		Losses		Fair Value
	NDT funds:
	PPL and PPL Energy Supply
			Cash and cash equivalents				$	14								$	14	$	11					$	11
			Equity securities					265		$	363						628		252	$	220				472
			Debt securities					217			7		$	3			221		211		19	$	1		229
			Receivables/payables, net					1									1
			Total NDT funds				$	497		$	370		$	3		$	864	$	474	$	239	$	1	$	712
	Auction rate securities:
		PPL					$	20					$	1		$	19	$	20			$	1	$	19
		PPL Energy Supply						17						1			16		17				1		16
Scheduled Maturity Dates of Debt Securities	'
	The following table shows the scheduled maturity dates of debt securities held at December 31, 2013.
				Maturity		Maturity			Maturity			Maturity
				Less Than		5-Jan			10-Jun			in Excess
				1 Year		Years			Years			of 10 Years			Total
	PPL
	Amortized cost			$	7	$	97		$	54		$	79		$	237
	Fair value				7		99			55			79			240
	PPL Energy Supply
	Amortized cost			$	7	$	97		$	54		$	76		$	234
	Fair value				7		99			55			76			237
Proceeds From and Realized Gains and Losses on Sales of Available-for-sale Securities	'
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities.
				2013		2012			2011
	PPL
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						5			163
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	PPL Energy Supply
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						3
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	(a)       These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
	(b)       Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.
PPL Energy Supply LLC [Member]	'
Available-for-Sale Securities [Line Items]	'
Available-for-Sale Securities	'
	The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of available-for-sale securities.
							December 31, 2013											December 31, 2012
										Gross			Gross							Gross		Gross
							Amortized			Unrealized			Unrealized					Amortized		Unrealized		Unrealized
							Cost			Gains			Losses			Fair Value		Cost		Gains		Losses		Fair Value
	NDT funds:
	PPL and PPL Energy Supply
			Cash and cash equivalents				$	14								$	14	$	11					$	11
			Equity securities					265		$	363						628		252	$	220				472
			Debt securities					217			7		$	3			221		211		19	$	1		229
			Receivables/payables, net					1									1
			Total NDT funds				$	497		$	370		$	3		$	864	$	474	$	239	$	1	$	712
	Auction rate securities:
		PPL					$	20					$	1		$	19	$	20			$	1	$	19
		PPL Energy Supply						17						1			16		17				1		16
Scheduled Maturity Dates of Debt Securities	'
	The following table shows the scheduled maturity dates of debt securities held at December 31, 2013.
				Maturity		Maturity			Maturity			Maturity
				Less Than		5-Jan			10-Jun			in Excess
				1 Year		Years			Years			of 10 Years			Total
	PPL
	Amortized cost			$	7	$	97		$	54		$	79		$	237
	Fair value				7		99			55			79			240
	PPL Energy Supply
	Amortized cost			$	7	$	97		$	54		$	76		$	234
	Fair value				7		99			55			76			237
Proceeds From and Realized Gains and Losses on Sales of Available-for-sale Securities	'
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities.
				2013		2012			2011
	PPL
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						5			163
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	PPL Energy Supply
	Proceeds from sales of NDT securities (a)			$	144	$	139		$	156
	Other proceeds from sales						3
	Gross realized gains (b)				17		29			28
	Gross realized losses (b)				7		21			16
	(a)       These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
	(b)       Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Tables)	12 Months Ended
	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated Other Comprehensive Income (Loss)	'
	AOCI, which is presented on the Balance Sheet of PPL and included in Member's equity on the Balance Sheets of PPL Energy Supply and LKE, consisted of the following after-tax gains (losses).
						Unrealized gains (losses)									Defined benefit plans
			Foreign
			currency			Available-						Equity			Prior			Actuarial			Transition
			translation			for-sale			Qualifying			investees'			service			gain			asset
			adjustments			securities			derivatives			AOCI			costs			(loss)			(obligation)			Total
	PPL
	December 31, 2010		$	-195		$	88		$	695		$	-4		$	-32		$	-1,032		$	1		$	-479
	OCI			-48			2			-168			3			7			-105						-309
	December 31, 2011		$	-243		$	90		$	527		$	-1		$	-25		$	-1,137		$	1		$	-788
	OCI			94			22			-395			2			11			-886						-1,152
	December 31, 2012		$	-149		$	112		$	132		$	1		$	-14		$	-2,023		$	1		$	-1,940
	Amounts arising during the period			138			67			45						2			71						323
	Reclassifications from AOCI						-6			-83						6			135						52
	Net OCI during the period			138			61			-38						8			206						375
	December 31, 2013		$	-11		$	173		$	94		$	1		$	-6		$	-1,817		$	1		$	-1,565
	PPL Energy Supply
	December 31, 2010		$	-195		$	88		$	733		$	-3		$	-23		$	-955					$	-355
	OCI						2			-86			3			2			-18						-97
	Distribution of membership
		interest in PPL Global (a)		195						-41						5			780						939
	December 31, 2011					$	90		$	606		$			$	-16		$	-193					$	487
	OCI						22			-395						6			-72						-439
	December 31, 2012		$			$	112		$	211		$			$	-10		$	-265					$	48
	Amounts arising during the period						67									2			71						140
	Reclassifications from AOCI						-6			-123						4			14						-111
	Net OCI during the period						61			-123						6			85						29
	December 31, 2013		$			$	173		$	88		$			$	-4		$	-180					$	77
	LKE
	December 31, 2010																	$	6					$	6
	OCI														$	-2									-2
	December 31, 2011														$	-2		$	6					$	4
	OCI											$	1						-20						-19
	December 31, 2012											$	1		$	-2		$	-14					$	-15
	Amounts arising during the period																		28						28
	Net OCI during the period																		28						28
	December 31, 2013											$	1		$	-2		$	14					$	13
Reclassification out of Other Comprehensive Income (Loss)	'
	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the year ended December 31, 2013.
				Affected Line Item on the Statements of Income
													Other
				Unregulated									Income
				wholesale			Energy			Interest			(Expense),						Total			Income			Total
	Details about AOCI			energy			purchases			Expense			net			Other			Pre-tax			Taxes			After-tax
	PPL
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Interest rate swaps								$	-20									-20			1			-19
		Cross-currency swaps									1			-28						-27			4			-23
		Energy commodities		$	263		$	-58								$	5			210			-85			125
		Total		$	263		$	-58		$	-19		$	-28		$	5			163			-80			83
	Defined benefit plans
		Prior service costs																		-10			4			-6
		Net actuarial loss																		-184			49			-135
		Total																	$	-194		$	53			-141
	Total reclassifications																								$	-52
	PPL Energy Supply
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Energy commodities		$	263		$	-58								$	2			207			-84			123
	Defined benefit plans
		Prior service costs																		-7			3			-4
		Net actuarial loss																		-24			10			-14
		Total																	$	-31		$	13			-18
	Total reclassifications																								$	111
PPL Energy Supply LLC [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated Other Comprehensive Income (Loss)	'
	AOCI, which is presented on the Balance Sheet of PPL and included in Member's equity on the Balance Sheets of PPL Energy Supply and LKE, consisted of the following after-tax gains (losses).
						Unrealized gains (losses)									Defined benefit plans
			Foreign
			currency			Available-						Equity			Prior			Actuarial			Transition
			translation			for-sale			Qualifying			investees'			service			gain			asset
			adjustments			securities			derivatives			AOCI			costs			(loss)			(obligation)			Total
	PPL
	December 31, 2010		$	-195		$	88		$	695		$	-4		$	-32		$	-1,032		$	1		$	-479
	OCI			-48			2			-168			3			7			-105						-309
	December 31, 2011		$	-243		$	90		$	527		$	-1		$	-25		$	-1,137		$	1		$	-788
	OCI			94			22			-395			2			11			-886						-1,152
	December 31, 2012		$	-149		$	112		$	132		$	1		$	-14		$	-2,023		$	1		$	-1,940
	Amounts arising during the period			138			67			45						2			71						323
	Reclassifications from AOCI						-6			-83						6			135						52
	Net OCI during the period			138			61			-38						8			206						375
	December 31, 2013		$	-11		$	173		$	94		$	1		$	-6		$	-1,817		$	1		$	-1,565
	PPL Energy Supply
	December 31, 2010		$	-195		$	88		$	733		$	-3		$	-23		$	-955					$	-355
	OCI						2			-86			3			2			-18						-97
	Distribution of membership
		interest in PPL Global (a)		195						-41						5			780						939
	December 31, 2011					$	90		$	606		$			$	-16		$	-193					$	487
	OCI						22			-395						6			-72						-439
	December 31, 2012		$			$	112		$	211		$			$	-10		$	-265					$	48
	Amounts arising during the period						67									2			71						140
	Reclassifications from AOCI						-6			-123						4			14						-111
	Net OCI during the period						61			-123						6			85						29
	December 31, 2013		$			$	173		$	88		$			$	-4		$	-180					$	77
	LKE
	December 31, 2010																	$	6					$	6
	OCI														$	-2									-2
	December 31, 2011														$	-2		$	6					$	4
	OCI											$	1						-20						-19
	December 31, 2012											$	1		$	-2		$	-14					$	-15
	Amounts arising during the period																		28						28
	Net OCI during the period																		28						28
	December 31, 2013											$	1		$	-2		$	14					$	13
	(a)       See Note 9 for additional information.
Reclassification out of Other Comprehensive Income (Loss)	'
	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the year ended December 31, 2013.
				Affected Line Item on the Statements of Income
													Other
				Unregulated									Income
				wholesale			Energy			Interest			(Expense),						Total			Income			Total
	Details about AOCI			energy			purchases			Expense			net			Other			Pre-tax			Taxes			After-tax
	PPL
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Interest rate swaps								$	-20									-20			1			-19
		Cross-currency swaps									1			-28						-27			4			-23
		Energy commodities		$	263		$	-58								$	5			210			-85			125
		Total		$	263		$	-58		$	-19		$	-28		$	5			163			-80			83
	Defined benefit plans
		Prior service costs																		-10			4			-6
		Net actuarial loss																		-184			49			-135
		Total																	$	-194		$	53			-141
	Total reclassifications																								$	-52
	PPL Energy Supply
	Available-for-sale securities												$	10					$	10		$	-4		$	6
	Qualifying derivatives
		Energy commodities		$	263		$	-58								$	2			207			-84			123
	Defined benefit plans
		Prior service costs																		-7			3			-4
		Net actuarial loss																		-24			10			-14
		Total																	$	-31		$	13			-18
	Total reclassifications																								$	111
LG And E And KU Energy LLC [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated Other Comprehensive Income (Loss)	'
	AOCI, which is presented on the Balance Sheet of PPL and included in Member's equity on the Balance Sheets of PPL Energy Supply and LKE, consisted of the following after-tax gains (losses).
						Unrealized gains (losses)									Defined benefit plans
			Foreign
			currency			Available-						Equity			Prior			Actuarial			Transition
			translation			for-sale			Qualifying			investees'			service			gain			asset
			adjustments			securities			derivatives			AOCI			costs			(loss)			(obligation)			Total
	PPL
	December 31, 2010		$	-195		$	88		$	695		$	-4		$	-32		$	-1,032		$	1		$	-479
	OCI			-48			2			-168			3			7			-105						-309
	December 31, 2011		$	-243		$	90		$	527		$	-1		$	-25		$	-1,137		$	1		$	-788
	OCI			94			22			-395			2			11			-886						-1,152
	December 31, 2012		$	-149		$	112		$	132		$	1		$	-14		$	-2,023		$	1		$	-1,940
	Amounts arising during the period			138			67			45						2			71						323
	Reclassifications from AOCI						-6			-83						6			135						52
	Net OCI during the period			138			61			-38						8			206						375
	December 31, 2013		$	-11		$	173		$	94		$	1		$	-6		$	-1,817		$	1		$	-1,565
	PPL Energy Supply
	December 31, 2010		$	-195		$	88		$	733		$	-3		$	-23		$	-955					$	-355
	OCI						2			-86			3			2			-18						-97
	Distribution of membership
		interest in PPL Global (a)		195						-41						5			780						939
	December 31, 2011					$	90		$	606		$			$	-16		$	-193					$	487
	OCI						22			-395						6			-72						-439
	December 31, 2012		$			$	112		$	211		$			$	-10		$	-265					$	48
	Amounts arising during the period						67									2			71						140
	Reclassifications from AOCI						-6			-123						4			14						-111
	Net OCI during the period						61			-123						6			85						29
	December 31, 2013		$			$	173		$	88		$			$	-4		$	-180					$	77
	LKE
	December 31, 2010																	$	6					$	6
	OCI														$	-2									-2
	December 31, 2011														$	-2		$	6					$	4
	OCI											$	1						-20						-19
	December 31, 2012											$	1		$	-2		$	-14					$	-15
	Amounts arising during the period																		28						28
	Net OCI during the period																		28						28
	December 31, 2013											$	1		$	-2		$	14					$	13

Quarterly_Financial_Informatio

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
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)
					31-Mar			30-Jun			Sept. 30			Dec. 31
	2013
	Operating revenues				$	2,457		$	3,450		$	3,105		$	2,848
	Operating income (e)					693			758			857			31
	Income (loss) from continuing operations after income taxes (e)					413			404			410			-98
	Income (loss) from discontinued operations								1			1
	Net income (loss) (e)					413			405			411			-98
	Net income (loss) attributable to PPL (e)					413			405			410			-98
	Income (loss) from continuing operations after income taxes available to
		PPL common shareowners: (b) (e)
			Basic EPS			0.7			0.68			0.65			-0.16
			Diluted EPS (d)			0.65			0.63			0.62			-0.16
	Net income (loss) available to PPL common shareowners: (b) (e)
			Basic EPS			0.7			0.68			0.65			-0.16
			Diluted EPS (d)			0.65			0.63			0.62			-0.16
	Dividends declared per share of common stock (c)					0.3675			0.3675			0.3675			0.3675
	Price per common share:
			High		$	31.35		$	33.55		$	32.09		$	31.79
			Low			28.64			28.44			29.03			28.95
	2012
	Operating revenues				$	4,112		$	2,549		$	2,403		$	3,222
	Operating income					1,051			572			664			822
	Income from continuing operations after income taxes					545			277			355			360
	Income (loss) from discontinued operations								-6
	Net income					545			271			355			360
	Net income attributable to PPL					541			271			355			359
	Income from continuing operations after income taxes available to
		PPL common shareowners: (b)
			Basic EPS			0.93			0.47			0.61			0.61
			Diluted EPS			0.93			0.47			0.61			0.6
	Net income available to PPL common shareowners: (b)
			Basic EPS			0.93			0.46			0.61			0.61
			Diluted EPS			0.93			0.46			0.61			0.6
	Dividends declared per share of common stock (c)					0.36			0.36			0.36			0.36
	Price per common share:
			High		$	29.85		$	28.44		$	29.98		$	30.18
			Low			27.29			26.68			27.72			27.74
	(a)       Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.
	(b)       The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.
	(c)       PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.
	(d)       As a result of a reported loss, diluted earnings per share for the three months ended December 31, 2013 exclude incremental shares as they were anti-dilutive.
	(e)       Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements 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)
				31-Mar			30-Jun			Sept. 30			Dec. 31
	2013
	Operating revenues		$	513		$	414		$	464		$	479
	Operating income			121			92			105			101
	Net income			64			45			51			49
	Net income available to PPL			64			45			51			49
	2012
	Operating revenues		$	458		$	404		$	444		$	457
	Operating income			79			63			71			81
	Net income			37			29			33			37
	Net income available to PPL			33			29			33			37
	(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_Account3

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
	Integer				Integer
Summary Of Significant Accounting Policies [Line Items]	'		'		'		'
Period of lag in reporting results for WPD Midlands (in months)	1		'		'		'
Months of operating results included in PPL's results for WPD Midlands for a specific period	'		'		8		'
Accumulated Other Comprehensive Income (Loss) [Abstract]	'		'		'		'
Total Accumulated Other Comprehensive Loss, Net of Tax	($1,565,000,000)		($1,940,000,000)		($788,000,000)		($479,000,000)
Utility Revenue (Details) [Abstract]	'		'		'		'
Domestic electric and gas revenue	4,842,000,000	[1]	4,519,000,000	[1]	4,674,000,000	[1]	'
U.K. electric revenue	2,359,000,000	[2]	2,289,000,000	[2]	1,618,000,000	[2]	'
Total	7,201,000,000		6,808,000,000		6,292,000,000		'
Revenue Recognition (Numeric) [Abstract]	'		'		'		'
Costs in excess of billings on uncompleted contracts or programs	14,000,000		12,000,000		'		'
Billings in excess of cost	75,000,000		70,000,000		'		'
Allowance for Doubtful Accounts (Details) [Roll Forward]	'		'		'		'
Additions charged to other accounts	'		'		'		'
Cash (Numeric) [Abstract]	'		'		'		'
Maximum maturity period for highly liquid debt instruments to be considered cash equivalents (in months)	3		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	156,000,000		135,000,000		'		'
Equity Method Investment [Abstract]	'		'		'		'
Income (loss) from investment	'		-8,000,000		1,000,000		'
Property, Plant and Equipment (Numeric) [Abstract]	'		'		'		'
Interest costs, capitalized during the period	46,000,000		53,000,000		51,000,000		'
Depreciation (Details) [Abstract]	'		'		'		'
Reduction in depreciation expense in 2013 as a result of lower weighted-average rates	22,000,000		'		'		'
Defined Benefits [Abstract]	'		'		'		'
Difference between the actual value of plan assets and the expected value	20.00%		'		'		'
The expected average remaining service of active plan participants	50.00%		'		'		'
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%		'		'		'
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%		'		'		'
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%		'		'		'
Income Taxes [Abstract]	'		'		'		'
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	702,000,000		673,000,000		'		'
Fuel [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	305,000,000		284,000,000		'		'
Natural Gas Stored Underground [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	49,000,000	[3]	50,000,000	[3]	'		'
Material And Supplies [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	348,000,000		339,000,000		'		'
Regulated Utility Plant [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	2.94%		3.12%		'		'
Nonregulated Property Plant And Equipment Generation [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	3.10%		3.05%		'		'
Nonregulated Property Plant And Equipment Generation [Member] | Brunner Island And Montour Plants [Member]	'		'		'		'
Asset Impairment (Excluding Investments) (Numeric) [Abstract]	'		'		'		'
Carrying value of utility plants	2,700,000,000		'		'		'
Nonregulated Property Plant And Equipment Generation [Member] | Brunner Island Plant [Member]	'		'		'		'
Asset Impairment (Excluding Investments) (Numeric) [Abstract]	'		'		'		'
Carrying value of utility plants	1,400,000,000		'		'		'
Nonregulated Property Plant And Equipment Generation [Member] | Montour Plant [Member]	'		'		'		'
Asset Impairment (Excluding Investments) (Numeric) [Abstract]	'		'		'		'
Carrying value of utility plants	1,300,000,000		'		'		'
Margin Deposits Posted To Counterparties [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	67,000,000		43,000,000		'		'
Cash Collateral Posted To Counterparties [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	22,000,000		32,000,000		'		'
Low Carbon Network Fund [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	27,000,000	[4]	14,000,000	[4]	'		'
Funds Deposited With Trustee [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	12,000,000	[5]	13,000,000	[5]	'		'
Ironwood Debt Service Reserves [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	17,000,000		17,000,000		'		'
Other Restricted Cash [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	11,000,000		16,000,000		'		'
Allowance For Doubtful Accounts [Member]	'		'		'		'
Allowance for Doubtful Accounts (Details) [Roll Forward]	'		'		'		'
Balance at beginning of period	64,000,000		54,000,000		55,000,000		'
Additions charged to income	39,000,000		55,000,000	[6]	65,000,000	[6]	'
Additions charged to other accounts	4,000,000		'		'		'
Deductions	43,000,000	[7]	45,000,000	[7]	66,000,000	[7],[8]	'
Balance at end of period	64,000,000		64,000,000		54,000,000		'
Unaffiliated Third Party Entity [Member]	'		'		'		'
Accounts Receivable (Numeric) [Abstract]	'		'		'		'
Purchases of accounts receivable	985,000,000		848,000,000		875,000,000		'
KU [Member] | Electric Energy Inc [Member]	'		'		'		'
Equity Method Investment [Abstract]	'		'		'		'
Ownership percentage	20.00%		'		'		'
Income (loss) from investment	'		8,000,000		'		'
Impairment charge	'		25,000,000		'		'
Impairment charge, after-tax	'		15,000,000		'		'
PPL Energy Supply LLC [Member]	'		'		'		'
Accumulated Other Comprehensive Income (Loss) [Abstract]	'		'		'		'
Total Accumulated Other Comprehensive Loss, Net of Tax	77,000,000		48,000,000		487,000,000		-355,000,000
Revenue Recognition (Numeric) [Abstract]	'		'		'		'
Costs in excess of billings on uncompleted contracts or programs	14,000,000		12,000,000		'		'
Billings in excess of cost	75,000,000		70,000,000		'		'
Cash (Numeric) [Abstract]	'		'		'		'
Maximum maturity period for highly liquid debt instruments to be considered cash equivalents (in months)	3		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	85,000,000		63,000,000		'		'
Property, Plant and Equipment (Numeric) [Abstract]	'		'		'		'
Interest costs, capitalized during the period	37,000,000		47,000,000		47,000,000		'
Defined Benefits [Abstract]	'		'		'		'
Difference between the actual value of plan assets and the expected value	20.00%		'		'		'
The expected average remaining service of active plan participants	50.00%		'		'		'
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%		'		'		'
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%		'		'		'
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%		'		'		'
Income Taxes [Abstract]	'		'		'		'
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%		'		'		'
Intercompany tax receivables (payables)	44,000,000		-38,000,000		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	358,000,000		327,000,000		'		'
PPL Energy Supply LLC [Member] | Fuel [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	163,000,000		135,000,000		'		'
PPL Energy Supply LLC [Member] | Natural Gas Stored Underground [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	2,000,000	[3]	8,000,000	[3]	'		'
PPL Energy Supply LLC [Member] | Material And Supplies [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	193,000,000		184,000,000		'		'
PPL Energy Supply LLC [Member] | Nonregulated Property Plant And Equipment Generation [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	3.10%		3.05%		'		'
PPL Energy Supply LLC [Member] | Nonregulated Property Plant And Equipment Generation [Member] | Brunner Island And Montour Plants [Member]	'		'		'		'
Asset Impairment (Excluding Investments) (Numeric) [Abstract]	'		'		'		'
Carrying value of utility plants	2,700,000,000		'		'		'
PPL Energy Supply LLC [Member] | Nonregulated Property Plant And Equipment Generation [Member] | Brunner Island Plant [Member]	'		'		'		'
Asset Impairment (Excluding Investments) (Numeric) [Abstract]	'		'		'		'
Carrying value of utility plants	1,400,000,000		'		'		'
PPL Energy Supply LLC [Member] | Nonregulated Property Plant And Equipment Generation [Member] | Montour Plant [Member]	'		'		'		'
Asset Impairment (Excluding Investments) (Numeric) [Abstract]	'		'		'		'
Carrying value of utility plants	1,300,000,000		'		'		'
PPL Energy Supply LLC [Member] | Margin Deposits Posted To Counterparties [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	67,000,000		43,000,000		'		'
PPL Energy Supply LLC [Member] | Ironwood Debt Service Reserves [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	17,000,000		17,000,000		'		'
PPL Energy Supply LLC [Member] | Other Restricted Cash [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	1,000,000		3,000,000		'		'
PPL Energy Supply LLC [Member] | Allowance For Doubtful Accounts [Member]	'		'		'		'
Allowance for Doubtful Accounts (Details) [Roll Forward]	'		'		'		'
Balance at beginning of period	23,000,000		15,000,000		20,000,000		'
Additions charged to income	1,000,000		12,000,000	[6]	14,000,000	[6]	'
Additions charged to other accounts	'		'		'		'
Deductions	3,000,000	[7]	4,000,000	[7]	19,000,000	[7],[8]	'
Balance at end of period	21,000,000		23,000,000		15,000,000		'
PPL Electric Utilities Corp [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	12,000,000		13,000,000		'		'
Defined Benefits [Abstract]	'		'		'		'
Difference between the actual value of plan assets and the expected value	20.00%		'		'		'
The expected average remaining service of active plan participants	50.00%		'		'		'
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%		'		'		'
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%		'		'		'
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%		'		'		'
Income Taxes [Abstract]	'		'		'		'
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%		'		'		'
Intercompany tax receivables (payables)	-19,000,000		22,000,000		'		'
PPL Electric Utilities Corp [Member] | Regulated Utility Plant [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	2.61%		2.57%		'		'
PPL Electric Utilities Corp [Member] | Funds Deposited With Trustee [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	12,000,000	[5]	13,000,000	[5]	'		'
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]	'		'		'		'
Allowance for Doubtful Accounts (Details) [Roll Forward]	'		'		'		'
Balance at beginning of period	18,000,000		17,000,000		17,000,000		'
Additions charged to income	32,000,000		32,000,000		33,000,000		'
Additions charged to other accounts	'		'		'		'
Deductions	32,000,000	[7]	31,000,000	[7]	33,000,000	[7]	'
Balance at end of period	18,000,000		18,000,000		17,000,000		'
PPL Electric Utilities Corp [Member] | Unaffiliated Third Party Entity [Member]	'		'		'		'
Accounts Receivable (Numeric) [Abstract]	'		'		'		'
Purchases of accounts receivable	985,000,000		848,000,000		875,000,000		'
PPL Electric Utilities Corp [Member] | Affiliated Entity [Member]	'		'		'		'
Accounts Receivable (Numeric) [Abstract]	'		'		'		'
Purchases of accounts receivable	294,000,000		313,000,000		264,000,000		'
LG And E And KU Energy LLC [Member]	'		'		'		'
Accumulated Other Comprehensive Income (Loss) [Abstract]	'		'		'		'
Total Accumulated Other Comprehensive Loss, Net of Tax	13,000,000		-15,000,000		4,000,000		6,000,000
Cash (Numeric) [Abstract]	'		'		'		'
Maximum maturity period for highly liquid debt instruments to be considered cash equivalents (in months)	3		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	22,000,000		32,000,000		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Reduction in depreciation expense in 2013 as a result of lower weighted-average rates	22,000,000		'		'		'
Defined Benefits [Abstract]	'		'		'		'
Difference between the actual value of plan assets and the expected value	20.00%		'		'		'
The expected average remaining service of active plan participants	50.00%		'		'		'
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%		'		'		'
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%		'		'		'
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%		'		'		'
Income Taxes [Abstract]	'		'		'		'
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%		'		'		'
Intercompany tax receivables (payables)	-28,000,000		-12,000,000		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	278,000,000		276,000,000		'		'
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	10		'		'		'
Number of companies power is supplied to	11		'		'		'
LG And E And KU Energy LLC [Member] | Fuel [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	141,000,000		149,000,000		'		'
LG And E And KU Energy LLC [Member] | Natural Gas Stored Underground [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	48,000,000	[3]	42,000,000	[3]	'		'
LG And E And KU Energy LLC [Member] | Material And Supplies [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	89,000,000		85,000,000		'		'
LG And E And KU Energy LLC [Member] | Regulated Utility Plant [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	4.07%		4.39%		'		'
LG And E And KU Energy LLC [Member] | Cash Collateral Posted To Counterparties [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	22,000,000		32,000,000		'		'
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	19,000,000		17,000,000		17,000,000		'
Additions charged to income	4,000,000		9,000,000		15,000,000		'
Additions charged to other accounts	4,000,000	[9]	'		'		'
Deductions	5,000,000	[7]	7,000,000	[7]	15,000,000	[7]	'
Balance at end of period	22,000,000		19,000,000		17,000,000		'
LG And E And KU Energy LLC [Member] | LGE [Member] | Ohio Valley Electric Corporation [Member]	'		'		'		'
Cost Method Investments [Abstract]	'		'		'		'
Ownership percentage	5.63%		'		'		'
Generation capacity in terms of ownership percentage (in MW)	120		'		'		'
LG And E And KU Energy LLC [Member] | KU [Member] | Ohio Valley Electric Corporation [Member]	'		'		'		'
Cost Method Investments [Abstract]	'		'		'		'
Ownership percentage	2.50%		'		'		'
Generation capacity in terms of ownership percentage (in MW)	53		'		'		'
LG And E And KU Energy LLC [Member] | KU [Member] | Electric Energy Inc [Member]	'		'		'		'
Equity Method Investment [Abstract]	'		'		'		'
Ownership percentage	20.00%		'		'		'
Income (loss) from investment	'		8,000,000		'		'
Impairment charge	'		25,000,000		'		'
Impairment charge, after-tax	'		15,000,000		'		'
Louisville Gas And Electric Co [Member]	'		'		'		'
Utility Revenue (Details) [Abstract]	'		'		'		'
Total	1,351,000,000		1,247,000,000		1,281,000,000		'
Cash (Numeric) [Abstract]	'		'		'		'
Maximum maturity period for highly liquid debt instruments to be considered cash equivalents (in months)	3		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	22,000,000		32,000,000		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Reduction in depreciation expense in 2013 as a result of lower weighted-average rates	8,000,000		'		'		'
Defined Benefits [Abstract]	'		'		'		'
Difference between the actual value of plan assets and the expected value	20.00%		'		'		'
The expected average remaining service of active plan participants	50.00%		'		'		'
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%		'		'		'
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%		'		'		'
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%		'		'		'
Income Taxes [Abstract]	'		'		'		'
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%		'		'		'
Intercompany tax receivables (payables)	-8,000,000		5,000,000		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	154,000,000		142,000,000		'		'
Louisville Gas And Electric Co [Member] | Ohio Valley Electric Corporation [Member]	'		'		'		'
Cost Method Investments [Abstract]	'		'		'		'
Number of electric utilities that are equity owners	10		'		'		'
Number of companies power is supplied to	11		'		'		'
Ownership percentage	5.63%		'		'		'
Generation capacity in terms of ownership percentage (in MW)	120		'		'		'
Louisville Gas And Electric Co [Member] | Fuel [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	64,000,000		61,000,000		'		'
Louisville Gas And Electric Co [Member] | Natural Gas Stored Underground [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	48,000,000	[3]	42,000,000	[3]	'		'
Louisville Gas And Electric Co [Member] | Material And Supplies [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	42,000,000		39,000,000		'		'
Louisville Gas And Electric Co [Member] | Regulated Utility Plant [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	4.52%		4.91%		'		'
Louisville Gas And Electric Co [Member] | Cash Collateral Posted To Counterparties [Member]	'		'		'		'
Restricted Cash and Cash Equivalents (Numeric) [Line Items]	'		'		'		'
Restricted cash and cash equivalents	22,000,000		32,000,000		'		'
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]	'		'		'		'
Allowance for Doubtful Accounts (Details) [Roll Forward]	'		'		'		'
Balance at beginning of period	1,000,000		2,000,000		2,000,000		'
Additions charged to income	2,000,000		2,000,000		5,000,000		'
Additions charged to other accounts	1,000,000	[9]	'		'		'
Deductions	2,000,000	[7]	3,000,000	[7]	5,000,000	[7]	'
Balance at end of period	2,000,000		1,000,000		2,000,000		'
Kentucky Utilities Co [Member]	'		'		'		'
Accumulated Other Comprehensive Income (Loss) [Abstract]	'		'		'		'
Total Accumulated Other Comprehensive Loss, Net of Tax	1,000,000		1,000,000		'		'
Utility Revenue (Details) [Abstract]	'		'		'		'
Total	1,625,000,000		1,512,000,000		1,512,000,000		'
Cash (Numeric) [Abstract]	'		'		'		'
Maximum maturity period for highly liquid debt instruments to be considered cash equivalents (in months)	3		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Reduction in depreciation expense in 2013 as a result of lower weighted-average rates	14,000,000		'		'		'
Defined Benefits [Abstract]	'		'		'		'
Difference between the actual value of plan assets and the expected value	20.00%		'		'		'
The expected average remaining service of active plan participants	50.00%		'		'		'
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%		'		'		'
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%		'		'		'
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%		'		'		'
Income Taxes [Abstract]	'		'		'		'
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%		'		'		'
Intercompany tax receivables (payables)	-27,000,000		-15,000,000		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	124,000,000		134,000,000		'		'
Kentucky Utilities Co [Member] | Ohio Valley Electric Corporation [Member]	'		'		'		'
Cost Method Investments [Abstract]	'		'		'		'
Number of electric utilities that are equity owners	10		'		'		'
Number of companies power is supplied to	11		'		'		'
Ownership percentage	2.50%		'		'		'
Generation capacity in terms of ownership percentage (in MW)	53		'		'		'
Kentucky Utilities Co [Member] | Electric Energy Inc [Member]	'		'		'		'
Equity Method Investment [Abstract]	'		'		'		'
Ownership percentage	20.00%		'		'		'
Income (loss) from investment	'		8,000,000		'		'
Impairment charge	'		25,000,000		'		'
Impairment charge, after-tax	'		15,000,000		'		'
Kentucky Utilities Co [Member] | Fuel [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	77,000,000		88,000,000		'		'
Kentucky Utilities Co [Member] | Material And Supplies [Member]	'		'		'		'
Fuel, Materials and Supplies (Details) [Line Items]	'		'		'		'
Fuel, materials and supplies on the Balance Sheet	47,000,000		46,000,000		'		'
Kentucky Utilities Co [Member] | Regulated Utility Plant [Member]	'		'		'		'
Depreciation (Details) [Abstract]	'		'		'		'
Weighted-average rates	3.77%		4.06%		'		'
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]	'		'		'		'
Allowance for Doubtful Accounts (Details) [Roll Forward]	'		'		'		'
Balance at beginning of period	2,000,000		2,000,000		6,000,000		'
Additions charged to income	3,000,000		4,000,000		6,000,000		'
Additions charged to other accounts	3,000,000	[9]	'		'		'
Deductions	4,000,000	[7]	4,000,000	[7]	10,000,000	[7]	'
Balance at end of period	$4,000,000		$2,000,000		$2,000,000		'
[1]	Represents revenue from regulated generation, transmission and/or distribution in Pennsylvania, Kentucky, Virginia and Tennessee, including regulated wholesale revenue.
[2]	Represents electric distribution revenue from the operation of WPD's distribution networks. 2011 includes eight months of revenue for WPD Midlands.
[3]	The majority of LKE's and LG&E's natural gas stored underground is held to serve retail customers. The majority of PPL Energy Supply's natural gas stored underground is available for resale.
[4]	Funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.
[5]	Funds deposited with a trustee to defease PPL Electric's 1945 First Mortgage Bonds.
[6]	Includes amounts related to the SMGT bankruptcy. See Note 15 for additional information.
[7]	Primarily related to uncollectible accounts written off.
[8]	Includes amounts related to the June 2011, FERC approved settlement agreement between PPL and the California ISO related to the sales made to the California ISO during the period October 2000 through June 2001 that were not paid to PPL subsidiaries. Therefore, the receivable and the related allowance for doubtful accounts were reversed and the settlement recorded.
[9]	Primarily related to capital projects, thus the provision was recorded as an adjustment to construction work in progress.

Segment_and_Related_Informatio2

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Integer

Segment Information (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Number of reportable segments

'

'

'

'

'

'

'

'

4

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

$11,860

$12,286

$12,737

Depreciation

'

'

'

'

'

'

'

'

1,161

1,100

960

Amortization

'

'

'

'

'

'

'

'

222

186

254

Unrealized (gains) losses on derivatives, and other hedging activities

'

'

'

'

'

'

'

'

236

27

-314

Interest Expenses

'

'

'

'

'

'

'

'

1,006

961

898

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

1,309

2,082

2,201

Income Taxes

'

'

'

'

'

'

'

'

180

545

691

Deferred income taxes and investment tax credits

'

'

'

'

'

'

'

'

72

[1]

426

[1]

584

[1]

Net Income Attributable to PPL Shareowners

-98

[2],[3]

410

[2]

405

[2]

413

[2]

359

[2]

355

[2]

271

[2]

541

[2]

1,130

1,526

1,495

Cash Flow [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Expenditures for long-lived assets

'

'

'

'

'

'

'

'

4,283

3,153

2,556

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

46,259

'

'

'

43,634

'

'

'

46,259

43,634

'

Segment (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Loss on lease termination for Colstrip coal-fired electric generating facility, pre-tax

'

'

'

'

'

'

'

'

697

'

'

Loss on lease termination for Colstrip coal-fired electric generating facility, after-tax

'

'

'

'

'

'

'

'

413

'

'

Kentucky Regulated [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Depreciation

'

'

'

'

'

'

'

'

334

346

334

Amortization

'

'

'

'

'

'

'

'

22

[4]

27

[4]

27

[4]

Unrealized (gains) losses on derivatives, and other hedging activities

'

'

'

'

'

'

'

'

12

[5]

11

[5]

9

[5]

Interest Expenses

'

'

'

'

'

'

'

'

212

219

217

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

484

263

349

Income Taxes

'

'

'

'

'

'

'

'

179

[6]

80

[6]

127

[6]

Deferred income taxes and investment tax credits

'

'

'

'

'

'

'

'

254

[1]

136

[1]

218

[1]

Net Income Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

307

177

221

Cash Flow [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Expenditures for long-lived assets

'

'

'

'

'

'

'

'

1,434

768

465

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

12,016

'

'

'

10,670

'

'

'

12,016

10,670

'

Kentucky Regulated [Member] | Utility Service [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

2,976

[7]

2,759

[7]

2,793

[7]

United Kingdom Regulated [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

2,403

2,336

1,653

Depreciation

'

'

'

'

'

'

'

'

300

279

218

Amortization

'

'

'

'

'

'

'

'

19

[4]

15

[4]

83

[4]

Unrealized (gains) losses on derivatives, and other hedging activities

'

'

'

'

'

'

'

'

-44

-52

8

Interest Expenses

'

'

'

'

'

'

'

'

425

421

391

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

993

953

358

Income Taxes

'

'

'

'

'

'

'

'

71

[6]

150

[6]

33

[6]

Deferred income taxes and investment tax credits

'

'

'

'

'

'

'

'

-45

[1]

26

[1]

-39

[1]

Net Income Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

922

803

325

Cash Flow [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Expenditures for long-lived assets

'

'

'

'

'

'

'

'

1,280

1,016

862

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

15,895

'

'

'

14,073

'

'

'

15,895

14,073

'

United Kingdom Regulated [Member] | Utility Service [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

2,359

[7]

2,289

[7]

1,618

[7]

United Kingdom Regulated [Member] | Energy Related Businesses [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

44

47

35

Pennsylvania Regulated [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Depreciation

'

'

'

'

'

'

'

'

178

160

146

Amortization

'

'

'

'

'

'

'

'

19

[4]

18

[4]

7

[4]

Interest Expenses

'

'

'

'

'

'

'

'

108

99

98

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

317

204

257

Income Taxes

'

'

'

'

'

'

'

'

108

[6]

68

[6]

68

[6]

Deferred income taxes and investment tax credits

'

'

'

'

'

'

'

'

127

[1]

114

[1]

106

[1]

Net Income Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

209

132

173

Cash Flow [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Expenditures for long-lived assets

'

'

'

'

'

'

'

'

942

633

490

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

6,846

'

'

'

6,023

'

'

'

6,846

6,023

'

Pennsylvania Regulated [Member] | Utility Service [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

1,866

[7]

1,760

[7]

1,881

[7]

Supply [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

4,602

5,431

6,410

Depreciation

'

'

'

'

'

'

'

'

318

289

245

Amortization

'

'

'

'

'

'

'

'

156

[4]

126

[4]

137

[4]

Unrealized (gains) losses on derivatives, and other hedging activities

'

'

'

'

'

'

'

'

180

[5]

-36

[5]

-315

[5]

Interest Expenses

'

'

'

'

'

'

'

'

228

222

192

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

-428

[5]

662

[5]

1,237

[5]

Income Taxes

'

'

'

'

'

'

'

'

-157

[6]

247

[6]

463

[6]

Deferred income taxes and investment tax credits

'

'

'

'

'

'

'

'

-296

[1]

150

[1]

299

[1]

Net Income Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

-272

[5],[8]

414

[5]

776

[5]

Cash Flow [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Expenditures for long-lived assets

'

'

'

'

'

'

'

'

568

736

739

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

11,408

'

'

'

12,868

'

'

'

11,408

12,868

'

Supply [Member] | Energy [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

4,075

[5]

4,970

[5]

5,938

[5]

Supply [Member] | Energy Related Businesses [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

527

461

472

Corporate And Other [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

13

'

'

Depreciation

'

'

'

'

'

'

'

'

31

26

17

Amortization

'

'

'

'

'

'

'

'

6

[4]

'

'

Interest Expenses

'

'

'

'

'

'

'

'

33

'

'

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

-57

'

'

Income Taxes

'

'

'

'

'

'

'

'

-21

[6]

'

'

Deferred income taxes and investment tax credits

'

'

'

'

'

'

'

'

32

[1]

'

'

Net Income Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

-36

'

'

Cash Flow [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Expenditures for long-lived assets

'

'

'

'

'

'

'

'

59

'

'

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

94

[9]

'

'

'

'

'

'

'

94

[9]

'

'

Intersegment Eliminations [Member] | Pennsylvania Regulated [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

4

3

11

Intersegment Eliminations [Member] | Supply [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

51

[10]

79

[10]

26

[10]

PPL Energy Supply LLC [Member]

'

'

'

'

'

'

'

'

'

'

'

Income Statement Data

'

'

'

'

'

'

'

'

'

'

'

Depreciation

'

'

'

'

'

'

'

'

318

285

244

Amortization

'

'

'

'

'

'

'

'

156

119

137

Unrealized (gains) losses on derivatives, and other hedging activities

'

'

'

'

'

'

'

'

171

-41

-283

Interest Expenses

'

'

'

'

'

'

'

'

171

168

174

Income from Continuing Operations Before Income Taxes

'

'

'

'

'

'

'

'

-371

738

1,212

Income Taxes

'

'

'

'

'

'

'

'

-142

[11]

263

[11]

445

[11]

Net Income Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

-230

474

768

Balance Sheet Data

'

'

'

'

'

'

'

'

'

'

'

Assets

11,074

'

'

'

12,375

'

'

'

11,074

12,375

'

Segment (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Loss on lease termination for Colstrip coal-fired electric generating facility, pre-tax

'

'

'

'

'

'

'

'

697

'

'

Loss on lease termination for Colstrip coal-fired electric generating facility, after-tax

'

'

'

'

'

'

'

'

$413

'

'

[1]

Represents a non-cash expense item that is also included in "Income Taxes."

[2]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[3]

Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements for additional information.

[4]

Represents non-cash expense items that include amortization of nuclear fuel, regulatory assets, debt discounts and premiums, debt issuance costs, emission allowances and RECs.

[5]

Includes unrealized gains and losses from economic activity. See Note 19 for additional information.

[6]

Represents both current and deferred income taxes, including investment tax credits.

[7]

See Note 1 for additional information on Utility Revenue.

[8]

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.

[9]

Primarily consists of unallocated items, including cash, PP&E and the elimination of inter-segment transactions.

[10]

See "PLR Contracts/Purchase of Accounts Receivable" in Note 16 for a discussion of the basis of accounting between reportable segments.

[11]

Excludes current and deferred federal, state and foreign tax expense (benefit) recorded to Discontinued Operations of $3 million in 2011. Also, excludes federal, state and foreign tax expense (benefit) recorded to OCI of $47 million in 2013, $(267) million in 2012 and $(83) million in 2011. The deferred tax benefit of operating loss carryforwards was insignificant for 2011.

Segment_and_Related_Informatio3

Segment and Related Information (Geographic Data) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues from External Customers and Long-Lived Assets [Line Items]	'	'	'
Revenues from external customers	$11,860	$12,286	$12,737
Long-lived assets	33,783	30,727	'
US [Member]	'	'	'
Revenues from External Customers and Long-Lived Assets [Line Items]	'	'	'
Revenues from external customers	9,457	9,950	11,084
Long-lived assets	22,638	20,776	'
UK [Member]	'	'	'
Revenues from External Customers and Long-Lived Assets [Line Items]	'	'	'
Revenues from external customers	2,403	2,336	1,653
Long-lived assets	$11,145	$9,951	'

Preferred_Securities_Details

Preferred Securities (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Jun. 30, 2012

Dec. 31, 2011

Oct. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preference Stock [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Preferred Stock [Member]

Preference Stock [Member]

Preference Stock [Member]

Preference Stock [Member]

Preferred Stock [Member]

Preferred Stock Without Par Value [Member]

Preferred Stock Without Par Value [Member]

Preference Stock Without Par Value [Member]

Preferred Securities [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividend requirements on noncontrolling interests

'

'

'

$4

$16

'

'

'

$4

$16

'

'

'

'

'

'

'

'

Shares authorized

'

'

'

'

'

10,000,000

'

'

'

'

20,629,936

'

'

10,000,000

1,720,000

6,750,000

5,300,000

2,000,000

Percentage rate on stock

'

'

'

'

'

'

'

'

'

'

'

'

6.25%

'

'

'

'

'

Date stock redemeed

'

'

'

'

'

'

30-Jun-12

'

'

'

'

30-Jun-12

'

'

'

'

'

'

Number of shares of stock redeemed

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

Aggregate value of stock redeemed

'

'

'

'

'

'

250

'

'

'

'

250

'

'

'

'

'

'

Value of stock redeemed including accumulated dividends

'

$250

'

'

'

'

'

'

$250

'

'

'

'

'

'

'

'

'

Par value of stock

'

'

'

'

'

'

'

'

'

'

'

$100

'

'

$25

'

'

'

No par value of stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares issued

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

Number of shares outstanding

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, except Share data in Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Income (Numerator)

'

'

'

'

'

'

'

'

'

'

'

Income from continuing operations after income taxes attributable to PPL shareowners

'

'

'

'

'

'

'

'

$1,128

$1,532

$1,493

Less amounts allocated to participating securities

'

'

'

'

'

'

'

'

6

8

6

Less issuance costs on subsidiary's preferred securities redeemed

'

'

'

'

'

'

'

'

'

6

'

Income from continuing operations after income taxes available to PPL common shareowners - Basic

'

'

'

'

'

'

'

'

1,122

1,518

1,487

Plus interest charges (net of tax) related to Equity Units

'

'

'

'

'

'

'

'

44

'

'

Income from continuing operations after income taxes available to PPL common shareowners - Diluted

'

'

'

'

'

'

'

'

1,166

1,518

1,487

Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted

'

1

[1]

1

[1]

'

'

'

-6

[1]

'

2

-6

2

Net income attributable to PPL shareowners

-98

[1],[2]

410

[1]

405

[1]

413

[1]

359

[1]

355

[1]

271

[1]

541

[1]

1,130

1,526

1,495

Less amounts allocated to participating securities

'

'

'

'

'

'

'

'

6

8

6

Less issuance costs on subsidiary's preferred securities redeemed

'

'

'

'

'

'

'

'

'

6

'

Net income available to PPL common shareowners - Basic

'

'

'

'

'

'

'

'

1,124

1,512

1,489

Plus interest charges (net of tax) related to Equity Units

'

'

'

'

'

'

'

'

44

'

'

Net income available to PPL common shareowners - Diluted

'

'

'

'

'

'

'

'

$1,168

$1,512

$1,489

Shares of Common Stock (Denominator)

'

'

'

'

'

'

'

'

'

'

'

Weighted-average shares - Basic EPS (in shares)

'

'

'

'

'

'

'

'

608,983

580,276

550,395

Add incremental non-participating securities:

'

'

'

'

'

'

'

'

'

'

'

Share-based payment awards (in shares)

'

'

'

'

'

'

'

'

1,062

[3]

563

[3]

400

[3]

Equity Units (in shares)

'

'

'

'

'

'

'

'

52,568

[4]

'

'

Forward sale agreements and Purchase Contracts (in shares)

'

'

'

'

'

'

'

'

460

[3]

787

[3]

157

[3]

Weighted-average shares - Diluted EPS (in shares)

'

'

'

'

'

'

'

'

663,073

581,626

550,952

Basic EPS - Available to PPL common shareowners:

'

'

'

'

'

'

'

'

'

'

'

Income from continuing operations after income taxes (in dollars per share)

($0.16)

[1],[2],[5]

$0.65

[1],[5]

$0.68

[1],[5]

$0.70

[1],[5]

$0.61

[1],[5]

$0.61

[1],[5]

$0.47

[1],[5]

$0.93

[1],[5]

$1.85

$2.62

$2.70

Income (loss) from discontinued operations (net of income taxes) (in dollars per share)

'

'

'

'

'

'

'

'

'

($0.01)

$0.01

Net Income (in dollars per share)

($0.16)

[1],[2],[5]

$0.65

[1],[5]

$0.68

[1],[5]

$0.70

[1],[5]

$0.61

[1],[5]

$0.61

[1],[5]

$0.46

[1],[5]

$0.93

[1],[5]

$1.85

$2.61

$2.71

Diluted EPS - Available to PPL common shareowners:

'

'

'

'

'

'

'

'

'

'

'

Income from continuing operations after income taxes (in dollars per share)

($0.16)

[1],[2],[5],[6]

$0.62

[1],[5],[6]

$0.63

[1],[5],[6]

$0.65

[1],[5],[6]

$0.60

[1],[5]

$0.61

[1],[5]

$0.47

[1],[5]

$0.93

[1],[5]

$1.76

$2.61

$2.70

Income (loss) from discontinued operations (net of income taxes) (in dollars per share)

'

'

'

'

'

'

'

'

'

($0.01)

'

Net Income (in dollars per share)

($0.16)

[1],[2],[5],[6]

$0.62

[1],[5],[6]

$0.63

[1],[5],[6]

$0.65

[1],[5],[6]

$0.60

[1],[5]

$0.61

[1],[5]

$0.46

[1],[5]

$0.93

[1],[5]

$1.76

$2.60

$2.70

Shares Issued (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Common stock issued under stock-based compensation plans (in shares)

'

'

'

'

'

'

'

'

1,552

[7]

'

'

Common stock issued under ESOP (in shares)

'

'

'

'

'

'

'

'

275

'

'

Common stock issued under DRIP (in shares)

'

'

'

'

'

'

'

'

549

'

'

Stock Options [Member]

'

'

'

'

'

'

'

'

'

'

'

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Shares excluded from the computations of diluted EPS

'

'

'

'

'

'

'

'

4,446

5,293

5,084

Performance Units [Member]

'

'

'

'

'

'

'

'

'

'

'

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Shares excluded from the computations of diluted EPS

'

'

'

'

'

'

'

'

55

58

2

Restricted Stock Units [Member]

'

'

'

'

'

'

'

'

'

'

'

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Shares excluded from the computations of diluted EPS

'

'

'

'

'

'

'

'

29

'

'

[1]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[2]

Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements for additional information.

[3]

The Treasury Stock Method was applied to non-participating share-based payment awards, forward sale agreements and the 2010 Purchase Contracts for 2012 and 2011

[4]

In 2013, the If-Converted Method was applied to the Equity Units prior to settlement.

[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]

As a result of a reported loss, diluted earnings per share for the three months ended December 31, 2013 exclude incremental shares as they were anti-dilutive.

[7]

Includes stock options exercised, 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 $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Income (Loss) from Continuing Operations (Details) [Abstract]	'		'	'
Domestic income	$196		$994	$1,715
Foreign income	1,113		1,088	486
Income (Loss) Before Income Taxes	1,309		2,082	2,201
Deferred Tax Assets	'		'	'
Deferred investment tax credits	137		130	'
Regulatory obligations	144		124	'
Accrued pension costs	140		276	'
Federal loss carryforwards	331		524	'
State loss carryforwards	304		305	'
Federal and state tax credit carryforwards	332		287	'
Foreign capital loss carryforwards	467		525	'
Foreign loss carryforwards	6		6	'
Foreign - pensions	202		254	'
Foreign - regulatory obligations	26		27	'
Foreign - other	12		16	'
Contributions in aid of construction	137		134	'
Domestic - other	211		239	'
Valuation allowances	-663		-706	'
Total deferred tax assets	1,786		2,141	'
Deferred Tax Liabilities	'		'	'
Domestic plant - net	4,073		3,967	'
Taxes recoverable through future rates	151		141	'
Unrealized gain on qualifying derivatives	37		122	'
Other regulatory assets	244		319	'
Reacquired debt costs	34		40	'
Foreign plant - net	859		937	'
Domestic - other	78		66	'
Total deferred tax liabilities	5,476		5,592	'
Net deferred tax liability	3,690		3,451	'
Federal [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	952	[1]	'	'
Federal [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-28		'	'
Federal [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-32		'	'
State [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	5,011	[1],[2]	'	'
Capital losses	125	[3]	'	'
State [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-14		'	'
Expiration - capital losses	31-Dec-14		'	'
State [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-33		'	'
Expiration - capital losses	31-Dec-16		'	'
Foreign [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	30	[4]	'	'
Capital losses	2,333	[5]	'	'
PPL Energy Supply LLC [Member]	'		'	'
Income (Loss) from Continuing Operations (Details) [Abstract]	'		'	'
Income (Loss) Before Income Taxes	-371		738	1,212
Deferred Tax Assets	'		'	'
Deferred investment tax credits	84		75	'
Accrued pension costs	39		94	'
Federal loss carryforwards	28		51	'
State loss carryforwards	80		79	'
Federal and state tax credit carryforwards	131		113	'
Domestic - other	69		68	'
Valuation allowances	-78		-74	'
Total deferred tax assets	353		406	'
Deferred Tax Liabilities	'		'	'
Domestic plant - net	1,392		1,579	'
Unrealized gain on qualifying derivatives	38		173	'
Domestic - other	46		44	'
Total deferred tax liabilities	1,476		1,796	'
Net deferred tax liability	1,123		1,390	'
PPL Energy Supply LLC [Member] | Federal [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	80		'	'
PPL Energy Supply LLC [Member] | Federal [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-31		'	'
PPL Energy Supply LLC [Member] | Federal [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-32		'	'
PPL Energy Supply LLC [Member] | State [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	1,204	[6]	'	'
PPL Energy Supply LLC [Member] | State [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-14		'	'
PPL Energy Supply LLC [Member] | State [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-33		'	'
PPL Electric Utilities Corp [Member]	'		'	'
Income (Loss) from Continuing Operations (Details) [Abstract]	'		'	'
Income (Loss) Before Income Taxes	317		204	257
Deferred Tax Assets	'		'	'
Regulatory obligations	38		24	'
Accrued pension costs	42		81	'
Federal loss carryforwards	72		81	'
State loss carryforwards	35		39	'
Contributions in aid of construction	109		106	'
Domestic - other	45		46	'
Total deferred tax assets	341		377	'
Deferred Tax Liabilities	'		'	'
Domestic plant - net	1,366		1,229	'
Taxes recoverable through future rates	129		122	'
Other regulatory assets	129		174	'
Reacquired debt costs	23		27	'
Domestic - other	8		12	'
Total deferred tax liabilities	1,655		1,564	'
Net deferred tax liability	1,314		1,187	'
PPL Electric Utilities Corp [Member] | Federal [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	206		'	'
PPL Electric Utilities Corp [Member] | Federal [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-31		'	'
PPL Electric Utilities Corp [Member] | Federal [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-32		'	'
PPL Electric Utilities Corp [Member] | State [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	534		'	'
PPL Electric Utilities Corp [Member] | State [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-30		'	'
PPL Electric Utilities Corp [Member] | State [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-32		'	'
LG And E And KU Energy LLC [Member]	'		'	'
Income (Loss) from Continuing Operations (Details) [Abstract]	'		'	'
Income (Loss) Before Income Taxes	551		331	419
Deferred Tax Assets	'		'	'
Deferred investment tax credits	52		54	'
Regulatory obligations	107		99	'
Accrued pension costs	26		42	'
Federal loss carryforwards	222		376	'
State capital loss carryforward	4		5	'
Income taxes due to customers	23		26	'
Federal and state tax credit carryforwards	179		170	'
Domestic - other	57		41	'
Valuation allowances	-4		-5	'
Total deferred tax assets	666		808	'
Deferred Tax Liabilities	'		'	'
Domestic plant - net	1,327		1,171	'
Other regulatory assets	133		152	'
Domestic - other	12		13	'
Total deferred tax liabilities	1,472		1,336	'
Net deferred tax liability	806		528	'
LG And E And KU Energy LLC [Member] | Federal [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	523		'	'
LG And E And KU Energy LLC [Member] | Federal [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-28		'	'
LG And E And KU Energy LLC [Member] | Federal [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-32		'	'
LG And E And KU Energy LLC [Member] | State [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	1,024		'	'
Capital losses	106		'	'
LG And E And KU Energy LLC [Member] | State [Member] | Minimum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-28		'	'
Expiration - capital losses	31-Dec-14		'	'
LG And E And KU Energy LLC [Member] | State [Member] | Maximum [Member]	'		'	'
Loss carryforwards	'		'	'
Expiration - operating losses	31-Dec-32		'	'
Expiration - capital losses	31-Dec-16		'	'
Louisville Gas And Electric Co [Member]	'		'	'
Income (Loss) from Continuing Operations (Details) [Abstract]	'		'	'
Income (Loss) Before Income Taxes	257		192	195
Deferred Tax Assets	'		'	'
Deferred investment tax credits	15		16	'
Regulatory obligations	59		54	'
Income taxes due to customers	19		21	'
Domestic - other	28		9	'
Total deferred tax assets	121		100	'
Deferred Tax Liabilities	'		'	'
Domestic plant - net	585		526	'
Other regulatory assets	83		86	'
Accrued pension costs	24		27	'
Domestic - other	8		9	'
Total deferred tax liabilities	700		648	'
Net deferred tax liability	579		548	'
Louisville Gas And Electric Co [Member] | Federal [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	10		'	'
Expiration - operating losses	31-Dec-32		'	'
Louisville Gas And Electric Co [Member] | State [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	22		'	'
Expiration - operating losses	31-Dec-30		'	'
Kentucky Utilities Co [Member]	'		'	'
Income (Loss) from Continuing Operations (Details) [Abstract]	'		'	'
Income (Loss) Before Income Taxes	360		215	282
Deferred Tax Assets	'		'	'
Deferred investment tax credits	38		38	'
Regulatory obligations	47		45	'
Accrued pension costs	'		-5	'
Federal loss carryforwards	23		20	'
Income taxes due to customers	4		5	'
Domestic - other	8		7	'
Total deferred tax assets	120		110	'
Deferred Tax Liabilities	'		'	'
Domestic plant - net	721		623	'
Other regulatory assets	50		65	'
Domestic - other	4		5	'
Total deferred tax liabilities	775		693	'
Net deferred tax liability	655		583	'
Kentucky Utilities Co [Member] | Federal [Member]	'		'	'
Loss carryforwards	'		'	'
Net operating losses	$65		'	'
Expiration - operating losses	31-Dec-32		'	'
[1]	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.
[2]	A valuation allowance of $185 million has been recorded against the deferred tax assets for these losses
[3]	A valuation allowance of $5 million has been recorded against the deferred tax assets for these losses.
[4]	A valuation allowance of $6 million has been recorded against the deferred tax assets for these losses.
[5]	A valuation allowance of $467 million has been recorded against the deferred tax assets for these losses.
[6]	A valuation allowance of $78 million has been recorded against the deferred tax assets for these losses.

Income_and_Other_Taxes_Credit_

Income and Other Taxes (Credit Carryforwards and Valuation Allowances and Reserves) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Valuation Allowances and Reserves (Details) [Roll Forward]	'		'		'
Additions charged to other accounts	'		'		'
Reduction of the valuation allowance as a result of the reduction in the UK statutory income tax rate	67,000,000		46,000,000		'
Permanently reinvested cumulative undistributed foreign earnings	2,900,000,000		2,000,000,000		'
Valuation Allowance Of Deferred Tax Assets [Member]	'		'		'
Valuation Allowances and Reserves (Details) [Roll Forward]	'		'		'
Balance at beginning of period	706,000,000		724,000,000		464,000,000
Additions charged to income	29,000,000		18,000,000		190,000,000
Additions charged to other accounts	'		10,000,000		112,000,000	[1]
Deductions	72,000,000	[2]	46,000,000	[2]	42,000,000	[2]
Balance at end of period	663,000,000		706,000,000		724,000,000
Valuation allowance recorded against certain deferred tax assets as a result of the WPD Midlands acquisition	'		'		101,000,000
Reduction of the valuation allowance as a result of the reduction in the UK statutory income tax rate	'		'		35,000,000
Investment Tax Credit [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	245,000,000		'		'
Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2025-12-31		'		'
Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2033-12-31		'		'
Alternative Minimum Tax Credit [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	32,000,000		'		'
Foreign Tax Credit [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	17,000,000		'		'
Foreign Tax Credit [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2017-12-31		'		'
Foreign Tax Credit [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2023-12-31		'		'
Other [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	35,000,000		'		'
Other [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2016-12-31		'		'
Other [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2033-12-31		'		'
Other [Member] | State [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	5,000,000		'		'
Expiration	'2022-12-31		'		'
PPL Energy Supply LLC [Member] | Valuation Allowance Of Deferred Tax Assets [Member]	'		'		'
Valuation Allowances and Reserves (Details) [Roll Forward]	'		'		'
Balance at beginning of period	74,000,000		72,000,000		408,000,000
Additions charged to income	4,000,000		2,000,000		22,000,000
Additions charged to other accounts	'		'		'
Deductions	'		'		358,000,000	[3]
Balance at end of period	78,000,000		74,000,000		72,000,000
PPL Energy Supply LLC [Member] | Investment Tax Credit [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	120,000,000		'		'
PPL Energy Supply LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2031-12-31		'		'
PPL Energy Supply LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2033-12-31		'		'
PPL Energy Supply LLC [Member] | Other [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	9,000,000		'		'
PPL Energy Supply LLC [Member] | Other [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2031-12-31		'		'
PPL Energy Supply LLC [Member] | Other [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2033-12-31		'		'
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	5,000,000		5,000,000		6,000,000
Additions charged to other accounts	'		'		'
Deductions	1,000,000	[4]	'		1,000,000	[4]
Balance at end of period	4,000,000		5,000,000		5,000,000
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	125,000,000		'		'
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2025-12-31		'		'
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2028-12-31		'		'
LG And E And KU Energy LLC [Member] | Alternative Minimum Tax Credit [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	28,000,000		'		'
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	26,000,000		'		'
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member] | Minimum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2016-12-31		'		'
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member] | Maximum [Member]	'		'		'
Credit carryforwards	'		'		'
Expiration	'2033-12-31		'		'
LG And E And KU Energy LLC [Member] | Other [Member] | State [Member]	'		'		'
Credit carryforwards	'		'		'
Credit carryforwards, amount	$9,000,000		'		'
Expiration	'2022-12-31		'		'
[1]	Primarily related to a $101 million valuation allowance that was recorded against certain deferred tax assets as a result of the 2011 acquisition of WPD Midlands. See Note 10 for additional information on the acquisition.
[2]	The reductions of the U.K. statutory income tax rate in 2013, 2012 and 2011 resulted in $67 million, $46 million and $35 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 of 2013, 2012 and 2011.
[3]	During 2011, PPL Energy Supply distributed its membership interest in PPL Global to PPL Energy Funding. See Note 9 for additional information.
[4]	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 $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
	Integer
Income Tax Expense (Benefit)	'		'		'
Current - Federal	($75)		'		$54
Current - State	1		-2		-20
Current - Foreign	181		121		73
Total Current Expense (Benefit)	107		119		107
Deferred - Federal	73		553		558
Deferred - State	45		103		127
Deferred - Foreign	-53		35		-23
Total Deferred Expense (Benefit), excluding operating loss carry forwards	65		691		662
Investment tax credit, net - Federal	-10		-10		-10
Tax expense (benefit) of operating loss carryforwards [Abstract]	'		'		'
Deferred - Federal	36	[1]	-195	[1]	-30
Deferred - State	-18		-60		-38
Total Tax Expense (Benefit) of Operating Loss Carryforwards	18		-255		-68
Total income tax from continuing operations	180		545		691
Income tax expense (benefit) from continuing operations [Abstract]	'		'		'
Total income tax expense - Federal	24		348		572
Total income tax expense (benefit) - State	28		41		69
Total income tax expense - Foreign	128		156		50
Total income tax from continuing operations	180		545		691
Discontinued Operation Tax Effect Of Discontinued Operation	1		-4		2
Stock-based compensation recorded to Additional Paid-in Capital	-2		-1		3
Issuance costs of Purchase Contracts recorded to Additional Paid-in Capital	'		'		-9
Reconciliation of Income Tax Expense	'		'		'
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%	458		729		770
Federal statutory rate	35.00%		35.00%		35.00%
Increase (decrease) due to:	'		'		'
State income taxes, net of federal income tax benefit	-7		27		63
State valuation allowance adjustments	24	[2]	13	[2]	36	[2]
Impact of lower U.K. income tax rates	-129	[3]	-110	[3]	-33	[3]
U.S. income tax on foreign earnings - net of foreign tax credit	9	[4]	26	[4]	-26	[4]
Federal and state tax reserve adjustments	-43	[5]	-1	[5]	39	[5]
Foreign tax reserve adjustments	-2		-5	[6]	-141	[6]
Federal and state income tax return adjustments	-5	[2]	16	[2],[7]	-17	[2],[7]
Foreign income tax return adjustments	-4		-6		'
Impact of the United Kingdom Finance Acts on deferred tax balances	-97	[3]	-75	[3]	-69	[3]
Federal income tax credits	-9	[8]	-12	[8]	-13	[8]
Depreciation not normalized	-8	[2]	-11	[2]	-20	[2]
Foreign valuation allowance adjustments	'		'		147	[6]
State deferred tax rate change	15	[9]	-19	[9]	-26	[9]
Net operating loss carryforward adjustments	'		-9	[10]	'
Intercompany interest on United Kingdom financing entities	-10	[11]	-9	[11]	-8	[11]
Other	-12		-9		-11
Total increase (decrease)	-278		-184		-79
Total income tax from continuing operations	180		545		691
Effective income tax rate	13.80%		26.20%		31.40%
Bonus depreciation percentage	'		100.00%		100.00%
Deferred tax expense recorded due to state clarification on treatment of bonus depreciation	'		'		43
Minimum property value for extended deadline for bonus depreciation	1		'		'
Minimum production period extended deadline for bonus depreciation (in years)	1		'		'
Minimum tax life for extended deadline for bonus depreciation (in years)	10		'		'
United Kingdom statutory income tax rate in effect during period prior to a change	23.00%		25.00%		27.00%
United Kingdom statutory income tax rate reduction	'		24.00%		26.00%
United Kingdom statutory income tax rate reduction in 2014	21.00%		'		'
United Kingdom statutory income tax rate reduction in 2015	20.00%		'		'
Expense (benefit) related to the recalculation of 2010 United Kingdom earnings and profits	-19		23		'
Tax benefit recorded due to United Kingdom pension contributions	'		'		28
Benefit from favorable United States Tax Court decision on deductibility of United Kingdom windfall profit tax	'		'		42
Expense from reversal by United States Court of Appeals for the Third Circuit on deductibility of United Kingdom windfall profit tax	'		'		-39
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		6		6
Benefit related to reversal of foreign tax reserves for capital losses	'		'		-147
Reversal of prior years' state income tax benefit related to regulated depreciation	'		-16		17
Benefit related to 2010 federal and state tax return adjustments related to domestic manufacturing deduction	'		5		7
Benefit related to 2010 federal and state tax return adjustments related to the flow through impact of Pennsylvania regulated state tax depreciation	'		'		3
Taxes, other than income	'		'		'
State gross receipts	135		135		140
State utility realty	2		2		-9
State capital stock	2		7		18
Foreign property	147		147		113
Domestic property and other	78		75		64
Total	364		366		326
PPL Energy Supply LLC [Member]	'		'		'
Income Tax Expense (Benefit)	'		'		'
Current - Federal	134		89		139
Current - State	21		22		-12
Total Current Expense (Benefit)	155		111		127
Deferred - Federal	-287		193		251
Deferred - State	-27		10		70
Total Deferred Expense (Benefit), excluding operating loss carry forwards	-314		203		321
Investment tax credit, net - Federal	-5		-2		-3
Tax expense (benefit) of operating loss carryforwards [Abstract]	'		'		'
Deferred - Federal	22	[1]	-48	[1]	'
Deferred - State	'		-1		'
Total Tax Expense (Benefit) of Operating Loss Carryforwards	22		-49		'
Total income tax from continuing operations	-142	[12]	263	[12]	445	[12]
Income tax expense (benefit) from continuing operations [Abstract]	'		'		'
Total income tax expense - Federal	-136		232		387
Total income tax expense (benefit) - State	-6		31		58
Total income tax from continuing operations	-142	[12]	263	[12]	445	[12]
Discontinued Operation Tax Effect Of Discontinued Operation	'		'		3
Other comprehensive income	47		-267		-83
Reconciliation of Income Tax Expense	'		'		'
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%	-130		258		424
Federal statutory rate	35.00%		35.00%		35.00%
Increase (decrease) due to:	'		'		'
State income taxes, net of federal income tax benefit	-22		33		60
State valuation allowance adjustments	4	[13]	2	[13]	22	[13]
Federal and state tax reserve adjustments	6	[14]	-2		2
Federal and state income tax return adjustments	-1		4		-22	[15]
Federal income tax credits	-8	[16]	-12	[16]	-12	[16]
State deferred tax rate change	15	[17]	-19	[17]	-26	[17]
Other	-6		-1		-3
Total increase (decrease)	-12		5		21
Total income tax from continuing operations	-142	[12]	263	[12]	445	[12]
Effective income tax rate	38.30%		35.60%		36.70%
Bonus depreciation percentage	'		'		100.00%
Benefit related to 2010 federal and state tax return adjustments related to domestic manufacturing deduction	'		7		'
Reversal of tax benefit related to a 2008 change in accounting method	3		'		'
Federal tax reserves related to differences in over (under) payment interest rates applied to audit claims as a result of the U.S. Supreme Court decision related to Windfall Profits tax	4		'		'
Taxes, other than income	'		'		'
State gross receipts	37		35		31
State capital stock	1		5		12
Domestic property and other	28		29		28
Total	66		69		71
PPL Electric Utilities Corp [Member]	'		'		'
Income Tax Expense (Benefit)	'		'		'
Current - Federal	-15		-28		-25
Current - State	-4		-18		-13
Total Current Expense (Benefit)	-19		-46		-38
Deferred - Federal	109		162		123
Deferred - State	16		42		25
Total Deferred Expense (Benefit), excluding operating loss carry forwards	125		204		148
Investment tax credit, net - Federal	-1		-1		-2
Tax expense (benefit) of operating loss carryforwards [Abstract]	'		'		'
Deferred - Federal	4		-72		-12
Deferred - State	-1		-17		-28
Total Tax Expense (Benefit) of Operating Loss Carryforwards	3		-89		-40
Total income tax from continuing operations	108		68		68
Income tax expense (benefit) from continuing operations [Abstract]	'		'		'
Total income tax expense - Federal	97		61		84
Total income tax expense (benefit) - State	11		7		-16
Total income tax from continuing operations	108		68		68
Reconciliation of Income Tax Expense	'		'		'
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%	111		71		90
Federal statutory rate	35.00%		35.00%		35.00%
Increase (decrease) due to:	'		'		'
State income taxes, net of federal income tax benefit	16		9		12
Federal and state tax reserve adjustments	-9	[18]	-8	[18]	-9	[18]
Federal and state income tax return adjustments	-1	[19]	7	[19]	-4	[19]
Amortization of investment tax credit	-1		-1		-2
Depreciation not normalized	-6	[20]	-8	[20]	-17	[20]
Other	-2		-2		-2
Total increase (decrease)	-3		-3		-22
Total income tax from continuing operations	108		68		68
Effective income tax rate	34.10%		33.30%		26.50%
Bonus depreciation percentage	'		100.00%		100.00%
Minimum property value for extended deadline for bonus depreciation	1		'		'
Minimum production period extended deadline for bonus depreciation (in years)	1		'		'
Minimum tax life for extended deadline for bonus depreciation (in years)	10		'		'
Benefit recorded related to stranded cost securitization included in change in federal and state income tax reserves	7		6		6
Expense (benefit) as a result of filing prior year federal and state income tax returns	'		'		-5
Reversal of prior years' state income tax benefit related to regulated depreciation	'		'		5
Benefit related to 2010 federal and state tax return adjustments related to the flow through impact of Pennsylvania regulated state tax depreciation	'		'		3
Taxes, other than income	'		'		'
State gross receipts	98		101		109
State utility realty	2		2		-10	[21]
State capital stock	1		1		4
Domestic property and other	2		1		1
Total	103		105		104
LG And E And KU Energy LLC [Member]	'		'		'
Income Tax Expense (Benefit)	'		'		'
Current - Federal	-59		-32		-71
Current - State	10		2		6
Total Current Expense (Benefit)	-49		-30		-65
Deferred - Federal	244		185		208
Deferred - State	20		15		16
Total Deferred Expense (Benefit), excluding operating loss carry forwards	264		200		224
Investment tax credit, net - Federal	-4		-6		-6
Tax expense (benefit) of operating loss carryforwards [Abstract]	'		'		'
Deferred - Federal	-4		-46		'
Deferred - State	-1		-12		'
Total Tax Expense (Benefit) of Operating Loss Carryforwards	-5		-58		'
Total income tax from continuing operations	206	[22]	106	[22]	153	[22]
Income tax expense (benefit) from continuing operations [Abstract]	'		'		'
Total income tax expense - Federal	177		101		131
Total income tax expense (benefit) - State	29		5		22
Total income tax from continuing operations	206	[22]	106	[22]	153	[22]
Discontinued Operation Tax Effect Of Discontinued Operation	-4		-4		-1
Other comprehensive income	-12		-12		-1
Reconciliation of Income Tax Expense	'		'		'
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%	193		116		147
Federal statutory rate	35.00%		35.00%		35.00%
Increase (decrease) due to:	'		'		'
State income taxes, net of federal income tax benefit	20		6		15
Amortization of investment tax credit	-4		-6		-5
Net operating loss carryforward adjustments	'	[10]	-9		'
Other	-3		-1		-4
Total increase (decrease)	13		-10		6
Total income tax from continuing operations	206	[22]	106	[22]	153	[22]
Effective income tax rate	37.40%		32.00%		36.50%
Taxes, other than income	'		'		'
Domestic property and other	48		46		37
Total	48		46		37
Louisville Gas And Electric Co [Member]	'		'		'
Income Tax Expense (Benefit)	'		'		'
Current - Federal	52		-2		12
Current - State	16		3		8
Total Current Expense (Benefit)	68		1		20
Deferred - Federal	33		65		52
Deferred - State	-2		6		2
Total Deferred Expense (Benefit), excluding operating loss carry forwards	31		71		54
Investment tax credit, net - Federal	-2		-3		-3
Tax expense (benefit) of operating loss carryforwards [Abstract]	'		'		'
Deferred - Federal	-3		'		'
Total Tax Expense (Benefit) of Operating Loss Carryforwards	-3		'		'
Total income tax from continuing operations	94		69		71
Income tax expense (benefit) from continuing operations [Abstract]	'		'		'
Total income tax expense - Federal	80		60		61
Total income tax expense (benefit) - State	14		9		10
Total income tax from continuing operations	94		69		71
Reconciliation of Income Tax Expense	'		'		'
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%	90		67		68
Federal statutory rate	35.00%		35.00%		35.00%
Increase (decrease) due to:	'		'		'
State income taxes, net of federal income tax benefit	10		5		7
Amortization of investment tax credit	-2		-3		-3
Other	-4		'		-1
Total increase (decrease)	4		2		3
Total income tax from continuing operations	94		69		71
Effective income tax rate	36.60%		35.90%		36.40%
Taxes, other than income	'		'		'
Domestic property and other	24		23		18
Total	24		23		18
Kentucky Utilities Co [Member]	'		'		'
Income Tax Expense (Benefit)	'		'		'
Current - Federal	51		-20		-8
Current - State	12		-1		4
Total Current Expense (Benefit)	63		-21		-4
Deferred - Federal	66		111		101
Deferred - State	8		11		10
Total Deferred Expense (Benefit), excluding operating loss carry forwards	74		122		111
Investment tax credit, net - Federal	-2		-3		-3
Tax expense (benefit) of operating loss carryforwards [Abstract]	'		'		'
Deferred - Federal	-3		-20		'
Total Tax Expense (Benefit) of Operating Loss Carryforwards	-3		-20		'
Total income tax from continuing operations	132	[23]	78	[23]	104	[23]
Income tax expense (benefit) from continuing operations [Abstract]	'		'		'
Total income tax expense - Federal	112		68		90
Total income tax expense (benefit) - State	20		10		14
Total income tax from continuing operations	132	[23]	78	[23]	104	[23]
Other comprehensive income	1		'		'
Reconciliation of Income Tax Expense	'		'		'
Federal income tax on Income (Loss) from Continuing Operations Before Income Taxes at statutory tax rate - 35%	126		75		99
Federal statutory rate	35.00%		35.00%		35.00%
Increase (decrease) due to:	'		'		'
State income taxes, net of federal income tax benefit	14		6		9
Amortization of investment tax credit	-2		-3		-3
Other	-6		'		-1
Total increase (decrease)	6		3		5
Total income tax from continuing operations	132	[23]	78	[23]	104	[23]
Effective income tax rate	36.70%		36.30%		36.90%
Taxes, other than income	'		'		'
Domestic property and other	24		23		19
Total	$24		$23		$19
[1]	A 2012 Federal income tax return adjustment was recorded in 2013 related to a reduction in the 2012 NOL recorded in the filed return. The reduction was primarily due to PPL's decision, at the time of filing, to utilize regular modified accelerated cost recovery system (MACRS) depreciation rates for certain non-regulated assets otherwise eligible for bonus tax depreciation.
[2]	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. During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. Due to the decrease in projected taxable income related to bonus depreciation and a decrease in projected future taxable income, PPL recorded $43 million in state deferred income tax expense related to deferred tax valuation allowances during 2011. Additionally, the 100% Pennsylvania bonus depreciation deduction created a current state income tax benefit for the flow-through impact of Pennsylvania regulated state tax depreciation. The federal provision for 100% bonus depreciation generally applies to property placed into service before January 1, 2012. The placed in-service deadline was extended to January 1, 2013 for property that had a cost in excess of $1 million, had a production period longer than one year and had a tax life of at least ten years. PPL’s tax deduction for 100% bonus regulated tax depreciation was zero in 2013 and was significantly lower in 2012 than in 2011.
[3]	The U.K. Finance Act 2013, enacted 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 related to both rate decreases. The U.K. Finance Act 2012, enacted in July 2012, reduced the U.K. statutory income tax rate from 25% to 24% retroactive to April 1, 2012 and from 24% to 23% effective April 1, 2013. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2012 related to both rate decreases. The U.K. Finance Act 2011, enacted in July 2011, reduced the U.K. statutory income tax rate from 27% to 26% retroactive to April 1, 2011 and from 26% to 25% effective April 1, 2012. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during 2011 related to both rate decreases.
[4]	During 2013, PPL recorded $25 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 reflected on an amended 2010 U.S. tax return. During 2012, PPL recorded a $23 million adjustment to federal income tax expense related to the recalculation of 2010 U.K. earnings and profits. During 2011, PPL recorded a $28 million federal income tax benefit related to U.K. pension contributions.
[5]	In 1997, the U.K. imposed a Windfall Profits Tax (WPT) on privatized utilities, including WPD. PPL filed its federal income tax returns for years subsequent to its 1997 and 1998 claims for refund on the basis that the U.K. WPT was creditable. In September 2010, the U.S. Tax Court (Tax Court) ruled in PPL’s favor in a dispute with the IRS, concluding that the U.K. WPT is a creditable tax for U.S. tax purposes. As a result, and with the finalization of other issues, PPL recorded a $42 million tax benefit in 2010. In January 2011, the IRS appealed the Tax Court’s decision to the U.S. Court of Appeals for the Third Circuit (Third Circuit). In December 2011, the Third Circuit issued its opinion reversing the Tax Court’s decision, holding that the U.K. WPT is not a creditable tax. As a result of the Third Circuit’s adverse determination, PPL recorded a $39 million expense in 2011. In June 2012, the U.S. Court of Appeals for the Fifth Circuit issued a contrary opinion in an identical case involving another company. In July 2012, PPL filed a petition for a writ of certiorari seeking U.S. Supreme Court review of the Third Circuit’s opinion. The Supreme Court granted PPL’s petition and oral argument was held in February 2013. On May 20, 2013, the Supreme Court reversed the Third Circuit’s opinion and ruled that the WPT is a creditable tax. As a result of the Supreme Court ruling, PPL recorded a tax benefit of $44 million during 2013, of which $19 million relates to interest. PPL recorded a tax benefit of $7 million during 2013 and $6 million during 2012 and 2011 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization is zero.
[6]	During 2012, PPL recorded a foreign tax benefit following resolution of a U.K. tax issue related to interest expense. During 2011, WPD reached an agreement with HMRC related to the amount of the capital losses that resulted from prior years’ restructuring in the U.K. and recorded a $147 million foreign tax benefit for the reversal of tax reserves related to the capital losses. Additionally, WPD recorded a $147 million valuation allowance for the amount of capital losses that, more likely than not, will not be utilized.
[7]	During 2012, PPL recorded $16 million in federal and state income tax expense related to the filing of the 2011 federal and state income tax returns. Of this amount, $5 million relates to the reversal of prior years’ state income tax benefits related to regulated depreciation. PPL changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year. In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates for network assets. The IRS guidance provided a safe harbor method of determining whether the repair expenditures for electric transmission and distribution property can be currently deducted for tax purposes. PPL adopted the safe harbor method with the filing of its 2011 federal income tax return. During 2011, PPL recorded $17 million in federal and state tax benefits related to the filing of the 2010 federal and state income tax returns. Of this amount, $7 million in tax benefits related to an additional domestic manufacturing deduction resulting from revised bonus depreciation amounts and $3 million in tax benefits related to the flow-through impact of Pennsylvania regulated state tax depreciation.
[8]	During 2013, 2012 and 2011, PPL recorded a deferred tax benefit related to investment tax credits on progress expenditures related to hydroelectric plant expansions. See Note 8 for additional information.
[9]	During 2013, 2012 and 2011, 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.
[10]	During 2012, LKE recorded adjustments to deferred taxes related to net operating loss carryforwards based on income tax return adjustments.
[11]	During 2013, 2012 and 2011, PPL recorded income tax benefits related to interest expense on intercompany loans.
[12]	Excludes current and deferred federal, state and foreign tax expense (benefit) recorded to Discontinued Operations of $3 million in 2011. Also, excludes federal, state and foreign tax expense (benefit) recorded to OCI of $47 million in 2013, $(267) million in 2012 and $(83) million in 2011. The deferred tax benefit of operating loss carryforwards was insignificant for 2011.
[13]	During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. Due to the decrease in projected taxable income related to bonus depreciation and a decrease in projected future taxable income, PPL Energy Supply recorded state deferred income tax expense related to deferred tax valuation allowances during 2011.
[14]	During 2013, PPL Energy Supply reversed $3 million in tax benefits related to a 2008 change in method of accounting for certain expenditures for tax purposes and recorded $4 million in federal tax expense related to differences in over (under) payment interest rates applied to audit claims as a result of the U.S. Supreme Court decision related to Windfall Profits Tax.
[15]	During 2011, PPL Energy Supply recorded federal and state tax benefits related to the filing of the 2010 federal and state income tax returns. Of this amount, $7 million in tax benefits related to an additional domestic manufacturing deduction resulting from revised bonus depreciation amounts.
[16]	During 2013, 2012 and 2011, PPL Energy Supply recorded a deferred tax benefit related to investment tax credits on progress expenditures related to hydroelectric plant expansions. See Note 8 for additional information.
[17]	During 2013, 2012 and 2011, PPL Energy Supply 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.
[18]	PPL Electric recorded a tax benefit of $7 million during 2013 and $6 million during 2012 and 2011 to federal and state income tax reserves related to stranded cost securitization. The reserve balance at December 31, 2013 related to stranded costs securitization is zero.
[19]	PPL Electric changed its method of accounting for repair expenditures for tax purposes effective for its 2008 tax year. In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates for network assets. The IRS guidance provided a safe harbor method of determining whether the repair expenditures for electric transmission and distribution property can be currently deducted for tax purposes. PPL Electric adopted the safe harbor method with the filing of its 2011 federal income tax return and recorded a $5 million adjustment to federal and state income tax expense resulting from the reversal of prior years’ state income tax benefits related to regulated depreciation. During 2011, PPL Electric recorded a $5 million federal and state income tax benefit as a result of filing its 2010 federal and state income tax returns. Of this amount, $3 million in tax benefits related to the flow-through impact of Pennsylvania regulated 100% bonus tax depreciation.
[20]	During 2011, the Pennsylvania Department of Revenue issued interpretive guidance on the treatment of bonus depreciation for Pennsylvania income tax purposes. The guidance allows 100% bonus depreciation for qualifying assets in the same year bonus depreciation is allowed for Federal income tax purposes. The 100% Pennsylvania bonus depreciation deduction created a current state income tax benefit for the flow-through impact of Pennsylvania regulated state tax depreciation. The federal provision for 100% bonus depreciation generally applies to property placed into service before January 1, 2012. The placed in service deadline was extended to January 1, 2013 for property that had a cost in excess of $1 million, had a production period longer that one year and had a tax life of at least ten years. PPL Electric’s tax deduction for 100% bonus depreciation was zero in 2013 and was significantly lower in 2012 than in 2011.
[21]	2011 includes PURTA tax that was refunded to PPL Electric customers in 2011.
[22]	Excludes current and deferred federal and state tax expense (benefit) recorded to Discontinued Operations of $1 million in 2013, $(4) million in 2012, and $(1) million in 2011. Also, excludes deferred federal and state tax expense (benefit) recorded to OCI of $18 million in 2013, $(12) million in 2012 and $(1) million in 2011.
[23]	Excludes deferred federal and state tax (benefit) recorded to OCI of less than $1 million in 2013 and $1 million in 2012.

Income_and_Other_Taxes_Unrecog

Income and Other Taxes (Unrecognized to End) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
	Integer
Unrecognized Tax Benefits (Details) [Roll Forward]	'		'	'
Beginning of period	$92		$145	'
Additions based on tax positions of prior years	3		15	'
Reductions based on tax positions of prior years	-32		-61	'
Additions based on tax positions related to the current year	'		7	'
Reductions based on tax positions related to the current year	'		-3	'
Settlements	-30		-2	'
Lapse of applicable statute of limitation	-11		-9	'
End of period	22		92	145
Unrecognized Tax Benefits - Probable Increase (Decrease) Next 12 Months (Details) [Abstract]	'		'	'
Total amount unrecognized tax benefits may increase in next 12 months	'		'	'
Total amount unrecognized tax benefits may decrease in next 12 months	22		'	'
Total unrecognized tax benefits and related effects that, if recognized, would decrease the effective tax rate	21		38	'
Open Tax Positions - Accrued Interest (Numeric) [Abstract]	'		'	'
Accrued interest receivable (payable) related to tax positions	15		-16	'
Open Tax Positions - Interest and Penalties (Numeric) [Abstract]	'		'	'
Interest expense (benefit) related to tax positions	-30		-4	27
Income Tax Examination (Details) [Line Items]	'		'	'
Number of major tax jurisdictions tax returns are filed	5		'	'
US - Federal [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'1997 and prior		'	'
Pennsylvania - State [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'2009 and prior		'	'
Kentucky - State [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'2008 and prior		'	'
Montana - State [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'2009 and prior		'	'
United Kingdom - Foreign [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'2011 and prior		'	'
PPL Energy Supply LLC [Member]	'		'	'
Unrecognized Tax Benefits (Details) [Roll Forward]	'		'	'
Beginning of period	30		28	'
Additions based on tax positions of prior years	'		4	'
Reductions based on tax positions of prior years	-15		-2	'
End of period	15		30	28
Unrecognized Tax Benefits - Probable Increase (Decrease) Next 12 Months (Details) [Abstract]	'		'	'
Total amount unrecognized tax benefits may increase in next 12 months	'		'	'
Total amount unrecognized tax benefits may decrease in next 12 months	15		'	'
Total unrecognized tax benefits and related effects that, if recognized, would decrease the effective tax rate	14		13	'
Open Tax Positions - Accrued Interest (Numeric) [Abstract]	'		'	'
Accrued interest receivable (payable) related to tax positions	15		17	'
Open Tax Positions - Interest and Penalties (Numeric) [Abstract]	'		'	'
Interest expense (benefit) related to tax positions	5		-4	6
Income Tax Examination (Details) [Line Items]	'		'	'
Number of major tax jurisdictions tax returns are filed	3		'	'
PPL Energy Supply LLC [Member] | US - Federal [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'1997 and prior		'	'
PPL Energy Supply LLC [Member] | Pennsylvania - State [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'2009 and prior		'	'
PPL Energy Supply LLC [Member] | Montana - State [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'2009 and prior		'	'
PPL Electric Utilities Corp [Member]	'		'	'
Unrecognized Tax Benefits (Details) [Roll Forward]	'		'	'
Beginning of period	26		73	'
Reductions based on tax positions of prior years	-17		-43	'
Additions based on tax positions related to the current year	'		5	'
Lapse of applicable statute of limitation	-9		-9	'
End of period	'		26	73
Unrecognized Tax Benefits - Probable Increase (Decrease) Next 12 Months (Details) [Abstract]	'		'	'
Total unrecognized tax benefits and related effects that, if recognized, would decrease the effective tax rate	'		3	'
Open Tax Positions - Accrued Interest (Numeric) [Abstract]	'		'	'
Accrued interest receivable (payable) related to tax positions	3		1	'
Open Tax Positions - Interest and Penalties (Numeric) [Abstract]	'		'	'
Interest expense (benefit) related to tax positions	($7)		($4)	($5)
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	'1997 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	'2008 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		'	'
Years no longer subject for recently acquired subsidiary	'3		'	'
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	'10/31/2010 and prior	[1]	'	'
Years no longer subject for recently acquired subsidiary	'ten month period ending October 31, 2010		'	'
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		'	'
Years no longer subject for recently acquired subsidiary	'3		'	'
Louisville Gas And Electric Co [Member] | US - Federal [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'10/31/2010 and prior	[1]	'	'
Years no longer subject for recently acquired subsidiary	'ten month period ending October 31, 2010		'	'
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		'	'
Years no longer subject for recently acquired subsidiary	'3		'	'
Kentucky Utilities Co [Member] | US - Federal [Member]	'		'	'
Income Tax Examination (Details) [Line Items]	'		'	'
Income tax examination, year(s) no longer under examination	'10/31/2010 and prior	[1]	'	'
Years no longer subject for recently acquired subsidiary	'ten month period ending October 31, 2010		'	'
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		'	'
[1]	 For LKE, LG&E, and KU, the ten month period ending October 31, 2010 remains open under the standard three year statute of limitations; however, the IRS has completed its audit of these periods under the Compliance Assurance Process, effectively closing them to audit adjustments. No issues remain outstanding.

Utility_Rate_Regulation_Regula

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	$33		$19		'
Noncurrent regulatory assets	1,246		1,483		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	90		61		'
Noncurrent regulatory liabilities	1,048		1,010		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Regulatory liability for deferred costs not yet approved by regulators	14		'		'
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]	'		'		'
Maximum recoverable cost	'		250		'
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]	'		'		'
Return on equity for approved projects remaining from earlier ECR plans	10.25%		'		'
Return on equity for approved projects in the 2009 ECR proceedings	'		10.63%		10.63%
Return on equity for approved projects in the 2011 ECR proceedings	'		10.10%		10.10%
Defined Benefit Plan Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-14		'		'
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		'		'
Unamortized Loss On Debt Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-40		'		'
Accumulated Cost Of Removal Of Utility Plant Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'five-year		'		'
Act 129 Compliance Rider Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'three-year		'		'
Amortization end date	31-May-16		31-May-13		'
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]	'		'		'
Maximum recoverable cost Phase II	185		'		'
Environmental Cost Recovery Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
Gas Supply Clause Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 18 months		'		'
Fuel Adjustments Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
Interest Rate Swaps Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-33		'		'
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]	'		'		'
Principal amount of debt related to interest rate swap that is receiving regulatory accounting treatment	500		'		'
Realized gains (losses) recognized during period that is receiving regulatory accounting treatment	86		'		'
Amortization end date for 2008 terminated swap contract	31-Dec-35		'		'
Gas Line Tracker Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Return on equity	10.25%		'		'
Coal Contracts Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-16		'		'
Power Purchase Agreement Ohio Valley Electric Corporation Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Mar-26		'		'
LGE [Member]	'		'		'
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]	'		'		'
Term, in years, of the gas service rider program	5		'		'
Generation Supply Charge [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	23		27		'
Environmental Cost Recovery [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	'		4		'
Gas Supply Clause [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	3		4		'
Gas Line Tracker [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	6		'		'
Transmission Service Charge [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	8		6		'
Transmission Formula Rate [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	20		'		'
Fuel Adjustment Clause [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	4		1		'
Universal Service Rider [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	10		17		'
Storm Damage Expense [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	14		'		'
Accumulated Cost Of Removal Of Utility Plant [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	688		679		'
Coal Contracts [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	98	[1]	141	[1]	'
Power Purchase Agreement Ohio Valley Electric Corporation [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	100	[1]	108	[1]	'
Net Deferred Tax Assets [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	30		34		'
Act 129 Compliance Rider [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	15		8		'
Defined Benefit Plans [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	26		17		'
Interest Rate Swaps [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	86		14		'
Other Regulatory Liabilities [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	2		2		'
Noncurrent regulatory liabilities	5		9		'
Gas Supply Clause [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	10		11		'
Fuel Adjustment Clause [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	2		6		'
Demand Side Management [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	8		1		'
Defined Benefit Plans [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	509		730		'
Taxes Recoverable Through Future Rates [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	306		293		'
Storm Costs [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	147		168		'
Unamortized Loss On Debt [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	85		96		'
Interest Rate Swaps [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	44		67		'
Accumulated Cost Of Removal Of Utility Plant [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	98		71		'
Asset Retirement Obligations [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	44		26		'
Environmental Cost Recovery [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	7		1		'
Other Regulatory Assets [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	6		'		'
Noncurrent regulatory assets	13		32		'
PPL Electric Utilities Corp [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	6		'		'
Noncurrent regulatory assets	772		853		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	76		52		'
Noncurrent regulatory liabilities	15		8		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Regulatory liability for deferred costs not yet approved by regulators	14		'		'
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]	'		'		'
Maximum recoverable cost	'		250		'
PPL Electric Utilities Corp [Member] | Defined Benefit Plan Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-14		'		'
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		'		'
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-29		'		'
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'five-year		'		'
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'three-year		'		'
Amortization end date	31-May-16		31-May-13		'
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]	'		'		'
Maximum recoverable cost Phase II	185		'		'
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	23		27		'
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	8		6		'
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	20		'		'
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	10		17		'
PPL Electric Utilities Corp [Member] | Storm Damage Expense [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	14		'		'
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	15		8		'
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	1		2		'
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	257		362		'
PPL Electric Utilities Corp [Member] | Taxes Recoverable Through Future Rates [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	306		293		'
PPL Electric Utilities Corp [Member] | Storm Costs [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	53		59		'
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	57		65		'
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	98		71		'
PPL Electric Utilities Corp [Member] | Other Regulatory Assets [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	6		'		'
Noncurrent regulatory assets	1		3		'
LG And E And KU Energy LLC [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	27		19		'
Noncurrent regulatory assets	474		630		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	14		9		'
Noncurrent regulatory liabilities	1,033		1,002		'
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]	'		'		'
Return on equity for approved projects remaining from earlier ECR plans	10.25%		'		'
Return on equity for approved projects in the 2009 ECR proceedings	'		10.63%		10.63%
Return on equity for approved projects in the 2011 ECR proceedings	'		10.10%		10.10%
LG And E And KU Energy LLC [Member] | Defined Benefit Plan Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-14		'		'
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		'		'
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-40		'		'
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
LG And E And KU Energy LLC [Member] | Gas Supply Clause Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 18 months		'		'
LG And E And KU Energy LLC [Member] | Fuel Adjustments Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
LG And E And KU Energy LLC [Member] | Interest Rate Swaps Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-33		'		'
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]	'		'		'
Principal amount of debt related to interest rate swap that is receiving regulatory accounting treatment	500		'		'
Realized gains (losses) recognized during period that is receiving regulatory accounting treatment	86		'		'
Amortization end date for 2008 terminated swap contract	31-Dec-35		'		'
LG And E And KU Energy LLC [Member] | Gas Line Tracker Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Return on equity	10.25%		'		'
LG And E And KU Energy LLC [Member] | Coal Contracts Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-16		'		'
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Mar-26		'		'
LG And E And KU Energy LLC [Member] | LGE [Member]	'		'		'
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]	'		'		'
Term, in years, of the gas service rider program	5		'		'
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	'		4		'
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	3		4		'
LG And E And KU Energy LLC [Member] | Gas Line Tracker [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	6		'		'
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	4		1		'
LG And E And KU Energy LLC [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	688		679		'
LG And E And KU Energy LLC [Member] | Coal Contracts [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	98	[1]	141	[1]	'
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	100	[1]	108	[1]	'
LG And E And KU Energy LLC [Member] | Net Deferred Tax Assets [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	30		34		'
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	26		17		'
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	86		14		'
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	1		'		'
Noncurrent regulatory liabilities	5		9		'
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	10		11		'
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	2		6		'
LG And E And KU Energy LLC [Member] | Demand Side Management [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	8		1		'
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	252		368		'
LG And E And KU Energy LLC [Member] | Storm Costs [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	94		109		'
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	28		31		'
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	44		67		'
LG And E And KU Energy LLC [Member] | Asset Retirement Obligations [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	44		26		'
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	7		1		'
LG And E And KU Energy LLC [Member] | Other Regulatory Assets [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	12		29		'
Louisville Gas And Electric Co [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	17		19		'
Noncurrent regulatory assets	303		400		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	9		4		'
Noncurrent regulatory liabilities	482		471		'
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]	'		'		'
Return on equity for approved projects remaining from earlier ECR plans	10.25%		'		'
Return on equity for approved projects in the 2009 ECR proceedings	'		10.63%		10.63%
Return on equity for approved projects in the 2011 ECR proceedings	'		10.10%		10.10%
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]	'		'		'
Term, in years, of the gas service rider program	5		'		'
Louisville Gas And Electric Co [Member] | Defined Benefit Plan Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-14		'		'
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	13		'		'
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-35		'		'
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
Louisville Gas And Electric Co [Member] | Gas Supply Clause Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 18 months		'		'
Louisville Gas And Electric Co [Member] | Fuel Adjustments Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
Louisville Gas And Electric Co [Member] | Interest Rate Swaps Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-33		'		'
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]	'		'		'
Principal amount of debt related to interest rate swap that is receiving regulatory accounting treatment	250		'		'
Realized gains (losses) recognized during period that is receiving regulatory accounting treatment	43		'		'
Amortization end date for 2008 terminated swap contract	31-Dec-35		'		'
Louisville Gas And Electric Co [Member] | Gas Line Tracker Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Return on equity	10.25%		'		'
Louisville Gas And Electric Co [Member] | Coal Contracts Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-16		'		'
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Mar-26		'		'
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	3		4		'
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	6		'		'
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	299		297		'
Louisville Gas And Electric Co [Member] | Coal Contracts [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	43	[1]	61	[1]	'
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	69	[1]	75	[1]	'
Louisville Gas And Electric Co [Member] | Net Deferred Tax Assets [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	26		28		'
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	43		7		'
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	'		'		'
Noncurrent regulatory liabilities	2		3		'
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	10		11		'
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	2		6		'
Louisville Gas And Electric Co [Member] | Demand Side Management [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	3		1		'
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	164		232		'
Louisville Gas And Electric Co [Member] | Storm Costs [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	51		59		'
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	18		20		'
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	44		67		'
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	21		15		'
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	2		1		'
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	5		7		'
Kentucky Utilities Co [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	10		'		'
Noncurrent regulatory assets	171		230		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	5		5		'
Noncurrent regulatory liabilities	551		531		'
Regulatory Assets and Liabilities - Environmental Cost Recovery (Numeric) [Abstract]	'		'		'
Return on equity for approved projects remaining from earlier ECR plans	10.25%		'		'
Return on equity for approved projects in the 2009 ECR proceedings	'		10.63%		10.63%
Return on equity for approved projects in the 2011 ECR proceedings	'		10.10%		10.10%
Kentucky Utilities Co [Member] | Defined Benefit Plan Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-14		'		'
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	6		'		'
Kentucky Utilities Co [Member] | Unamortized Loss On Debt Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization end date	31-Dec-40		'		'
Kentucky Utilities Co [Member] | Environmental Cost Recovery Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
Kentucky Utilities Co [Member] | Gas Supply Clause Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 18 months		'		'
Kentucky Utilities Co [Member] | Fuel Adjustments Combined Asset And Liability [Member]	'		'		'
Regulatory Assets And Liabilities [Line Items]	'		'		'
Amortization period	'within 12 months		'		'
Period of recurring reviews of activity	'six-month		'		'
Period of when rider amounts are rolled into base rates	'two-year		'		'
Kentucky Utilities Co [Member] | Interest Rate Swaps Combined Asset And Liability [Member]	'		'		'
Regulatory Assets and Liabilities - Interest Rate Swaps (Numeric) [Abstract]	'		'		'
Principal amount of debt related to interest rate swap that is receiving regulatory accounting treatment	250		'		'
Realized gains (losses) recognized during period that is receiving regulatory accounting treatment	43		'		'
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	'		4		'
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	4		1		'
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	389		382		'
Kentucky Utilities Co [Member] | Coal Contracts [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	55	[1]	80	[1]	'
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	31	[1]	33	[1]	'
Kentucky Utilities Co [Member] | Net Deferred Tax Assets [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	4		6		'
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	26		17		'
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Noncurrent regulatory liabilities	43		7		'
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]	'		'		'
Regulatory Liabilities [Line Items]	'		'		'
Current regulatory liabilities	1		'		'
Noncurrent regulatory liabilities	3		6		'
Kentucky Utilities Co [Member] | Demand Side Management [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	5		'		'
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	88		136		'
Kentucky Utilities Co [Member] | Storm Costs [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	43		50		'
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	10		11		'
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	23		11		'
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Current regulatory assets	5		'		'
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]	'		'		'
Regulatory Assets [Line Items]	'		'		'
Noncurrent regulatory assets	$7		$22		'
[1]	These liabilities were recorded as offsets to certain intangible assets that were recorded at fair value upon the acquisition of LKE by PPL.

Utility_Rate_Regulation_Regula1

Utility Rate Regulation (Regulatory Matters) (Details) (USD $)

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Oct. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Integer

PPL Electric [Member]

PPL Electric [Member]

PPL Electric [Member]

PPL Electric [Member]

PPL Electric [Member]

PPL Electric [Member]

LGE [Member]

LGE [Member]

LGE [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Pennsylvania 2011 Storms [Member]

Pennsylvania 2012 Storms [Member]

Pennsylvania 2012 Storms [Member]

Pennsylvania 2012 Storms [Member]

Distribution Rates [Member]

Kentucky August 2011 Storms [Member]

Kentucky August 2011 Storms [Member]

Electric Rates [Member]

Gas Rates [Member]

Electric Rates [Member]

Integer

Pennsylvania 2011 Storms [Member]

Pennsylvania 2012 Storms [Member]

Pennsylvania 2012 Storms [Member]

Pennsylvania 2012 Storms [Member]

Distribution Rates [Member]

Kentucky August 2011 Storms [Member]

LGE [Member]

LGE [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

Kentucky August 2011 Storms [Member]

Kentucky August 2011 Storms [Member]

Electric Rates [Member]

Gas Rates [Member]

Integer

Electric Rates [Member]

Integer

Integer

Integer

Integer

Integer

Kentucky August 2011 Storms [Member]

Electric Rates [Member]

Gas Rates [Member]

Electric Rates [Member]

Integer

Integer

Integer

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability at period end regarding line loss incentive/penalty

$74

$94

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

WPD's credit to income statement for Distribution Price Control Review 4 liability

79

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

45

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction in liability for line loss liability, in 2013, resulting from refunds included in tariffs and foreign exchange movements

66

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum potential loss exposure regarding line loss incentive/penalty

74

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum potential loss exposure regarding line loss incentive/penalty

213

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Matters - Rate Case Proceeding (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Return on equity request included in rate case

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.70%

'

'

Dollar amount of increase to rates

'

'

'

'

'

'

'

71

'

'

'

34

15

'

51

'

'

'

'

'

'

71

'

'

'

'

34

15

'

51

'

'

'

'

34

15

'

'

51

Reduction in depreciation expense in 2013 as a result of lower weighted-average rates

22

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22

'

'

'

'

'

'

'

8

'

'

'

'

'

14

'

'

Return on equity increase resulting from approved increase to rates

'

'

10.40%

'

'

'

'

'

10.25%

'

'

'

'

10.25%

'

'

10.40%

'

'

'

'

'

'

'

10.25%

'

'

'

10.25%

'

'

10.25%

'

'

'

'

'

10.25%

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Under Act 129, percentage cap on costs that can be recovered for implementation of EE and C plan

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Under Act 129, percentage reduction in electricity consumption by 2011

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Under Act 129, percentage reduction in electricity consumption by 2013

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Under Act 129, percentage reduction in peak demand electricity consumption by 2013

4.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of hours that are the benchmark for demand reductions by 2013

100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of years EDCs have to comply with consumption reduction target

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Under Act 129, percentage reduction in electricity target for the company under the Phase II program

2.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of modifications filed to Phase II plan

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Matters - Pennsylvania Activities - Public Utility Commission Investigation of Retail Electricity Market (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of phases of a PUC investigation of retail electricity market

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of ratemaking mechanisms authorized for PUC approval

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum term for Long Term Infrastructure Improvement Plan (in years)

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum term for Long Term Infrastructure Improvement Plan (in years)

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of issues assigned to the Office of Administrative Law Judge

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Matters - Storm Costs (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of customers impacted by storm

'

'

'

'

'

'

'

'

'

'

139,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

139,000

'

'

'

'

'

'

'

139,000

'

'

'

'

'

Total storm restoration costs incurred

'

'

'

84

66

'

81

'

'

'

'

'

'

'

'

'

'

84

66

'

81

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Storm restoration costs recorded to statement of income

'

'

'

54

50

'

61

'

'

'

'

'

'

'

'

'

'

54

50

'

61

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total probable insurance recoveries recorded

'

'

'

26.5

'

'

18.25

'

'

'

'

'

'

'

'

'

'

26.5

'

'

18.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total probable insurance recoveries recorded to statement of income

'

'

'

16

'

'

14

'

'

'

'

'

'

'

'

'

'

16

'

'

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of regulatory asset established

'

'

'

$25

'

$29

$28

'

'

'

$8

'

'

'

'

'

'

$25

'

$29

$28

'

'

'

'

$8

'

'

'

'

'

'

'

$8

'

'

'

'

'

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

'

'

'

5

'

'

'

'

'

5

'

'

'

'

'

'

'

5

'

'

'

'

'

5

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12

'

'

Financing_Activities_Credit_Ar

Financing Activities (Credit Arrangements) (Details)

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Syndicated Credit Facility [Member]

PPL WW [Member]

PPL WW [Member]

WPD South West [Member]

WPD South West [Member]

WPD East Midlands [Member]

WPD East Midlands [Member]

WPD West Midlands [Member]

WPD West Midlands [Member]

WPD [Member]

WPD [Member]

WPD [Member]

PPL Capital Funding [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Electric [Member]

PPL Electric [Member]

LKE [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

KU [Member]

KU [Member]

KU [Member]

KU [Member]

US [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

USD ($)

USD Denominated Borrowing [Member]

USD Denominated Borrowing [Member]

Syndicated Credit Facility [Member]

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Uncommitted Credit Facilities [Member]

Uncommitted Credit Facilities [Member]

Letter Of Credit Facility [Member]

Letter Of Credit Facility [Member]

Facility Agreement [Member]

Secured Trading Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Letter Of Credit Facility [Member]

Letter Of Credit Facility [Member]

Syndicated Credit Facility [Member]

PPL WW [Member]

PPL WW [Member]

WPD South West [Member]

WPD East Midlands [Member]

WPD West Midlands [Member]

WPD [Member]

WPD [Member]

WPD [Member]

WPD [Member]

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Uncommitted Credit Facilities [Member]

Uncommitted Credit Facilities [Member]

Letter Of Credit Facility [Member]

Letter Of Credit Facility [Member]

Facility Agreement [Member]

Secured Trading Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

LKE [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

KU [Member]

KU [Member]

KU [Member]

KU [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Letter Of Credit Facility [Member]

Letter Of Credit Facility [Member]

GBP (£)

GBP (£)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

GBP (£)

GBP (£)

Uncommitted Credit Facilities [Member]

Uncommitted Credit Facilities [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

USD ($)

USD ($)

Syndicated Credit Facility [Member]

Syndicated Credit Facility [Member]

Letter Of Credit Facility [Member]

Letter Of Credit Facility [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Integer

GBP (£)

GBP (£)

GBP (£)

GBP (£)

GBP (£)

GBP (£)

GBP (£)

Integer

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Financing Activities [Line Items]

'

'

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'

'

'

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'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expiration date

'

21-Dec-16

'

12-Jan-17

'

16-Apr-16

'

16-Apr-16

'

'

'

'

'

'

'

6-Nov-17

'

'

'

31-Mar-14

'

30-Jun-17

3-Nov-18

18-Oct-17

'

30-Oct-18

6-Nov-17

'

'

'

6-Nov-17

'

1-May-16

'

12-Nov-18

'

'

'

'

'

'

'

'

'

'

'

6-Nov-17

'

'

'

31-Mar-14

'

30-Jun-17

3-Nov-18

18-Oct-17

'

30-Oct-18

6-Nov-17

'

'

'

6-Nov-17

'

1-May-16

'

6-Nov-17

'

'

'

6-Nov-17

'

1-May-16

'

Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

$3,325,000,000

'

$3,000,000,000

[1],[2]

'

$175,000,000

[2]

'

$150,000,000

[2]

'

'

'

$300,000,000

[1],[2]

'

$75,000,000

[1],[2]

$500,000,000

[1],[2]

'

$598,000,000

'

$400,000,000

[1],[2]

'

$198,000,000

[1],[2],[3]

'

$300,000,000

[1],[2]

£ 210,000,000

[1],[4]

'

£ 245,000,000

[1],[4]

£ 300,000,000

[1],[4],[5]

£ 300,000,000

[1],[4],[5]

£ 1,139,000,000

[6]

'

£ 84,000,000

'

$3,325,000,000

'

$3,000,000,000

[1],[2]

'

$175,000,000

[2]

'

$150,000,000

[2]

'

'

'

$300,000,000

[1],[2]

'

$75,000,000

[1],[2]

$500,000,000

[1],[2]

'

$598,000,000

'

$400,000,000

[1],[2]

'

$198,000,000

[1],[2],[3]

'

$500,000,000

[1],[2]

'

$598,000,000

'

$400,000,000

[1],[2]

'

$198,000,000

[1],[2],[3]

'

Borrowed

'

'

'

'

'

'

'

'

'

'

166,000,000

171,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

75,000,000

[1],[2],[7]

'

'

'

'

'

'

'

'

270,000,000

[1],[2],[7]

103,000,000

[1],[4]

106,000,000

[1],[4]

'

'

'

103,000,000

[6]

106,000,000

[6]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

75,000,000

[1],[2],[7]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letters of credit issued and commercial paper backstop

'

'

'

'

'

'

'

'

'

'

'

'

'

244,000,000

671,000,000

29,000,000

[1],[2]

499,000,000

[1],[2]

77,000,000

[2]

40,000,000

[2]

138,000,000

[2]

132,000,000

[2]

'

'

21,000,000

[1],[2]

1,000,000

[1],[2]

'

20,000,000

[1],[2]

55,000,000

[1],[2]

348,000,000

268,000,000

150,000,000

[1],[2]

70,000,000

[1],[2]

198,000,000

[1],[2],[3]

198,000,000

[1],[2],[3]

'

'

'

'

'

'

5,000,000

[6]

4,000,000

[6]

5,000,000

4,000,000

244,000,000

671,000,000

29,000,000

[1],[2]

499,000,000

[1],[2]

77,000,000

[2]

40,000,000

[2]

138,000,000

[2]

132,000,000

[2]

'

'

21,000,000

[1],[2]

1,000,000

[1],[2]

'

20,000,000

[1],[2]

55,000,000

[1],[2]

348,000,000

268,000,000

150,000,000

[1],[2]

70,000,000

[1],[2]

198,000,000

[1],[2],[3]

198,000,000

[1],[2],[3]

20,000,000

[1],[2]

55,000,000

[1],[2]

348,000,000

268,000,000

150,000,000

[1],[2]

70,000,000

[1],[2]

198,000,000

[1],[2],[3]

198,000,000

[1],[2],[3]

Unused capacity

'

'

'

'

'

'

'

'

'

1,700,000,000

'

'

'

3,081,000,000

'

2,971,000,000

[1],[2]

'

98,000,000

[2]

'

12,000,000

[2]

'

'

'

279,000,000

[1],[2]

'

'

480,000,000

[1],[2]

'

250,000,000

'

250,000,000

[1],[2]

'

'

'

30,000,000

[1],[2]

107,000,000

[1],[4]

'

245,000,000

[1],[4]

300,000,000

[1],[4],[5]

300,000,000

[1],[4],[5]

1,031,000,000

[6]

'

79,000,000

'

3,081,000,000

'

2,971,000,000

[1],[2]

'

98,000,000

[2]

'

12,000,000

[2]

'

'

'

279,000,000

[1],[2]

'

'

480,000,000

[1],[2]

'

250,000,000

'

250,000,000

[1],[2]

'

'

'

480,000,000

[1],[2]

'

250,000,000

'

250,000,000

[1],[2]

'

'

'

Minimum interest coverage ratio allowed under the credit facility

'

'3.0 times

'3.0 times

'3.0 times

'3.0 times

'3.0 times

'3.0 times

'3.0 times

'3.0 times

'

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'

'

'

'

'

'

'

Maximum percentage of total net debt to RAV allowed under the credit facility

'

85.00%

85.00%

85.00%

85.00%

85.00%

85.00%

85.00%

85.00%

'

'

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'

'

'

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'

'

'

Maximum amount of letters of credit that may be issued under credit facility

'

'

'

'

'

80,000,000

'

80,000,000

'

'

'

'

'

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'

'

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'

'

'

'

Interest rate on outstanding borrowing

'

'

'

'

'

'

'

'

'

'

1.87%

0.85%

1.79%

'

'

'

'

'

'

'

'

'

'

'

'

1.67%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.67%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum percentage of debt to total capitalization allowed under the credit facility

70.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65.00%

65.00%

65.00%

65.00%

'

'

'

'

70.00%

70.00%

'

70.00%

70.00%

'

'

70.00%

70.00%

70.00%

70.00%

'

'

'

'

'

'

'

'

'

'

'

'

65.00%

65.00%

65.00%

65.00%

'

'

'

'

70.00%

70.00%

70.00%

70.00%

70.00%

'

'

70.00%

70.00%

70.00%

70.00%

70.00%

70.00%

'

'

70.00%

70.00%

70.00%

70.00%

Potential capacity increase

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

100,000,000

'

25,000,000

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

100,000,000

'

25,000,000

100,000,000

'

'

'

100,000,000

'

'

'

'

'

'

'

100,000,000

'

'

'

Potential maximum Facility Agreement capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Secured energy marketing and trading facility capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate carrying value of mortgages

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Automatic renewal term (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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1

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1

'

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'

'

'

'

'

'

'

'

[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 capitalization not to exceed 65% for PPL Energy Supply and 70% for PPL, 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 credit facilities and subject to certain conditions, PPL Energy Supply may request that its facility's capacity be increased by up to $500 million, PPL Electric and KU each may request up to a $100 million increase in its facility's capacity and LKE may request up to a $25 million increase in its facility's capacity.

[3]

KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted to loans rather than requiring immediate payment.

[4]

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.

[5]

Under these facilities, WPD (East Midlands) and WPD (West Midlands) each have the ability to request the lenders to issue up to £80 million of letters of credit in lieu of borrowing.

[6]

PPL WW's amounts borrowed at December 31, 2013 and 2012 were USD-denominated borrowings of $166 million and $171 million, which equated to £103 million and £106 million at the time of the borrowings and bore interest at 1.87% and 0.85%. At December 31, 2013, the unused capacity of WPD's credit facilities was approximately $1.7 billion.

[7]

PPL Capital Funding's and LKE's borrowings at December 31, 2013 bore interest at 1.79% and 1.67%, respectively.

Financing_Activities_Shortterm

Financing Activities (Short-term Debt) (Details)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

31-May-11

Apr. 30, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Commercial Paper [Member]

Commercial Paper [Member]

Bridge Loan 2011 [Member]

Bridge Loan 2011 [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Electric [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL WEM [Member]

PPL WEM [Member]

PPL WEM [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

USD ($)

USD ($)

Expired Short Term Debt Facility [Member]

Expired Short Term Debt Facility [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Bridge Loan 2011 [Member]

Bridge Loan 2011 [Member]

Bridge Loan 2011 [Member]

Bridge Loan 2011 [Member]

Bridge Loan 2011 [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

USD ($)

GBP (£)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Expired Short Term Debt Facility [Member]

Expired Short Term Debt Facility [Member]

Expired Short Term Debt Facility [Member]

Expired Short Term Debt Facility [Member]

Expired Short Term Debt Facility [Member]

USD ($)

USD ($)

USD ($)

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

GBP (£)

GBP (£)

GBP (£)

GBP (£)

USD ($)

USD ($)

USD ($)

USD ($)

Short-term Debt [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capacity

$1,750,000,000

'

'

'

$750,000,000

'

$300,000,000

$350,000,000

'

$350,000,000

'

'

'

'

'

'

$750,000,000

'

$300,000,000

$350,000,000

'

$350,000,000

'

$350,000,000

'

$350,000,000

'

Commercial paper issuances

190,000,000

481,000,000

'

'

'

356,000,000

20,000,000

20,000,000

55,000,000

150,000,000

70,000,000

'

'

'

'

'

'

356,000,000

20,000,000

20,000,000

55,000,000

150,000,000

70,000,000

20,000,000

55,000,000

150,000,000

70,000,000

Weighted-average interest rate

'

'

'

'

'

0.50%

0.23%

0.29%

0.42%

0.32%

0.42%

'

'

'

'

'

'

0.50%

0.23%

0.29%

0.42%

0.32%

0.42%

0.29%

0.42%

0.32%

0.42%

Unused capacity

1,560,000,000

'

'

'

750,000,000

'

280,000,000

330,000,000

'

200,000,000

'

'

'

'

'

'

750,000,000

'

280,000,000

330,000,000

'

200,000,000

'

330,000,000

'

200,000,000

'

Original committed capacity of Bridge Facility

'

'

'

3,600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fees incurrred in connection with Bridge Facility

'

'

44,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowings during period on short-term facility

'

'

'

'

'

'

'

'

'

'

'

'

1,750,000,000

'

'

1,850,000,000

'

'

'

'

'

'

'

'

'

'

'

Interest rate on facility

'

'

'

'

'

'

'

'

'

'

'

2.62%

2.62%

'

'

2.62%

'

'

'

'

'

'

'

'

'

'

'

Repayments during period on short-term facility

'

'

'

'

'

'

'

'

'

'

'

$2,800,000,000

'

£ 1,200,000,000

£ 650,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Financing_Activities_Longterm_

Financing Activities (Long-term Debt and Equity Securities) (Details)

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

Jul. 31, 2013

Apr. 30, 2012

Apr. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2011

Dec. 31, 2013

31-May-13

Apr. 30, 2013

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Nov. 30, 2013

Nov. 30, 2013

Oct. 31, 2013

Sep. 30, 2013

Oct. 31, 2013

Sep. 30, 2013

Oct. 31, 2013

Oct. 31, 2013

31-May-13

31-May-13

31-May-13

31-May-13

Mar. 31, 2013

31-May-13

31-May-13

31-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 28, 2013

Dec. 31, 2013

Feb. 28, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Feb. 28, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 28, 2013

Feb. 28, 2013

Feb. 28, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

USD ($)

Integer

USD ($)

USD ($)

USD ($)

USD ($)

Equity Units 2011 [Member]

Equity Units 2011 [Member]

Forward Sale Agreement [Member]

Forward Sale Agreement [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Electric [Member]

LKE [Member]

LGE [Member]

KU [Member]

WPD East Midlands [Member]

WPD East Midlands [Member]

WPD East Midlands [Member]

WPD East Midlands [Member]

WPD West Midlands [Member]

WPD West Midlands [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

PPL Capital Funding [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

US [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

UK [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

USD ($)

USD ($)

USD ($)

USD ($)

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Index Linked Senior Unsecured Notes [Member]

Index Linked Senior Unsecured Notes [Member]

Index Linked Senior Unsecured Notes [Member]

Index Linked Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Junior Subordinated Notes [Member]

Junior Subordinated Notes [Member]

Junior Subordinated Notes [Member]

Junior Subordinated Notes [Member]

Junior Subordinated Notes [Member]

USD ($)

USD ($)

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Junior Subordinated Notes [Member]

Junior Subordinated Notes [Member]

Other [Member]

Other [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Energy Supply [Member]

PPL Electric [Member]

PPL Electric [Member]

PPL Electric [Member]

LKE [Member]

LKE [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

PPL Capital Funding [Member]

PPL Ironwood [Member]

USD ($)

GBP (£)

USD ($)

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Index Linked Senior Unsecured Notes [Member]

Index Linked Senior Unsecured Notes [Member]

WPD South West And WPD East Midlands [Member]

WPD South West And WPD East Midlands [Member]

WPD South West [Member]

WPD South West [Member]

USD ($)

USD ($)

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Secured Notes [Member]

Senior Secured Notes [Member]

Other [Member]

Other [Member]

US [Member]

US [Member]

US [Member]

USD ($)

USD ($)

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

Other [Member]

Other [Member]

USD ($)

USD ($)

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

LGE [Member]

LGE [Member]

LGE [Member]

KU [Member]

KU [Member]

KU [Member]

US [Member]

USD ($)

USD ($)

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

US [Member]

USD ($)

USD ($)

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

US [Member]

EquityUnits

Integer

USD ($)

USD ($)

USD ($)

USD ($)

Tax Exempt Revenue Bonds [Member]

USD ($)

USD ($)

USD ($)

USD ($)

GBP (£)

GBP (£)

USD ($)

GBP (£)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Secured Notes [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Junior Subordinated Notes [Member]

Senior Secured Notes [Member]

USD ($)

USD ($)

USD ($)

USD ($)

Index Linked Senior Unsecured Notes [Member]

Index Linked Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

Senior Unsecured Notes [Member]

USD ($)

USD ($)

USD ($)

USD ($)

REset Put Securities [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Senior Unsecured Notes [Member]

Senior Secured Notes [Member]

PPL Ironwood [Member]

USD ($)

USD ($)

2001 Mortgage Indenture [Member]

2001 Mortgage Indenture [Member]

Pollution Control Revenue Refunding Bonds [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Tax Exempt Revenue Bonds [Member]

Insured Auction Rate Securities [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

USD ($)

USD ($)

USD ($)

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

Tax Exempt Revenue Bonds [Member]

Insured Auction Rate Securities [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

USD ($)

USD ($)

USD ($)

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

Tax Exempt Revenue Bonds [Member]

Insured Auction Rate Securities [Member]

Senior Secured Notes - First Mortgage Bonds [Member]

USD ($)

Integer

USD ($)

REset Put Securities [Member]

2001 Mortgage Indenture [Member]

2001 Mortgage Indenture [Member]

Pollution Control Revenue Refunding Bonds [Member]

Tax Exempt Revenue Bonds [Member]

Insured Auction Rate Securities [Member]

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

USD ($)

USD ($)

GBP (£)

USD ($)

GBP (£)

USD ($)

USD ($)

Senior Secured Notes [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

USD ($)

2010 Mortgage Indenture [Member]

2010 Mortgage Indenture [Member]

Tax Exempt Revenue Bonds [Member]

USD ($)

USD ($)

USD ($)

USD ($)

Tax Exempt Revenue Bonds [Member]

USD ($)

USD ($)

USD ($)

USD ($)

Tax Exempt Revenue Bonds [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-Average Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.31%

'

3.80%

'

5.29%

'

6.95%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.53%

'

1.83%

'

'

'

'

'

'

'

5.32%

'

5.32%

'

'

'

'

8.86%

'

6.00%

'

'

'

'

'

'

4.63%

'

'

'

'

'

7.38%

'

'

'

3.31%

'

3.18%

'

'

'

'

'

'

'

'

'

'

'

'

'

2.77%

'

'

'

'

'

'

'

'

'

3.44%

'

'

'

'

'

'

Maturity date of long-term debt range start

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Aug-14

'

1-Nov-15

'

1-May-19

'

1-Mar-14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1-May-16

'

1-Jun-43

'

'

'

'

'

'

'

'

'

15-Aug-14

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Dec-15

'

'

'

'

'

'

'

'

'

15-Nov-15

'

1-Nov-15

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Nov-15

'

'

'

'

'

'

'

'

'

1-Nov-15

'

'

'

'

'

'

Maturity date of long-term date range end

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Jun-43

'

15-Nov-43

'

30-Apr-73

'

30-Nov-20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10-Dec-40

'

1-Dec-56

'

'

'

'

'

'

'

'

'

1-Dec-38

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Jul-43

'

'

'

'

'

'

'

'

'

1-Oct-21

'

15-Nov-43

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Nov-43

'

'

'

'

'

'

'

'

'

15-Nov-43

'

'

'

'

'

'

Principal outstanding

'

'

'

$20,935,000,000

$19,435,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$13,314,000,000

$12,716,000,000

$5,568,000,000

[1]

$4,506,000,000

[1]

$5,823,000,000

[2],[3],[4],[5]

$5,587,000,000

[2],[3],[4],[5]

$1,908,000,000

$2,608,000,000

$15,000,000

$15,000,000

'

$300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

$7,621,000,000

[6]

'

$6,719,000,000

[6]

$6,872,000,000

[7]

$6,111,000,000

[7]

$749,000,000

[8]

$608,000,000

[8]

'

'

'

'

$2,547,000,000

$3,249,000,000

$2,493,000,000

[1]

'

$2,493,000,000

[1]

$2,581,000,000

[1]

$300,000,000

'

'

$49,000,000

[5]

$663,000,000

[5]

$5,000,000

$5,000,000

'

'

'

$2,324,000,000

$1,974,000,000

$2,314,000,000

[2],[4]

$1,964,000,000

[2],[4]

'

'

'

'

$10,000,000

$10,000,000

$4,585,000,000

$4,085,000,000

$1,125,000,000

$1,125,000,000

$3,460,000,000

[2],[3]

$2,960,000,000

[2],[3]

'

'

'

'

'

'

'

'

'

$1,359,000,000

$1,109,000,000

'

$1,359,000,000

[2],[3]

$1,109,000,000

[2],[3]

'

'

'

'

'

$2,101,000,000

$1,851,000,000

'

$2,101,000,000

[2],[3]

$1,851,000,000

[2],[3]

'

'

'

'

'

Maturity date (in years)

'

'

'

'

'

'

'

'

'

'

21-Dec-13

15-Jul-13

'

'

15-Jul-43

'

15-Nov-43

15-Nov-43

24-Sep-52

24-Sep-52

'

'

17-Oct-24

17-Oct-24

1-Jun-18

1-Jun-23

1-Jun-43

'

30-Apr-73

1-Jul-18

1-Jun-16

1-Jun-18

'

'

'

'

'

'

'

'

'

'

15-Dec-21

31-Dec-35

30-Nov-25

'

'

'

'

'

'

'

'

'

1-May-19

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21-Dec-13

15-Jul-13

'

'

31-Dec-35

'

'

30-Nov-25

'

30-Nov-20

'

15-Dec-21

30-Nov-25

'

'

'

'

'

'

'

'

15-Jul-43

1-Mar-14

'

'

'

'

'

'

'

'

'

15-Nov-43

'

'

15-Nov-43

'

'

'

'

'

15-Nov-43

'

'

'

'

'

'

'

'

'

15-Nov-43

'

'

'

'

'

'

'

Fair market value adjustments

'

'

'

23,000,000

78,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-22,000,000

22,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,000,000

7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,000,000

6,000,000

'

'

'

'

'

'

'

'

1,000,000

1,000,000

'

'

'

'

'

'

'

'

Unamortized premium and (discount), net

'

'

'

-51,000,000

-37,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-9,000,000

-7,000,000

'

'

'

'

'

'

'

'

-19,000,000

-17,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-5,000,000

-3,000,000

'

'

'

'

'

'

'

'

-11,000,000

-10,000,000

'

'

'

'

'

'

'

'

Total Long-term Debt

'

'

'

20,907,000,000

19,476,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,525,000,000

3,272,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,315,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Less current portion of Long-term debt

'

'

'

315,000,000

751,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

304,000,000

751,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt

'

'

'

20,592,000,000

18,725,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,221,000,000

2,521,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,305,000,000

1,967,000,000

'

'

'

'

'

'

'

'

4,565,000,000

4,075,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

1,353,000,000

1,112,000,000

'

'

'

'

'

'

'

'

2,091,000,000

1,842,000,000

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

'

'

'

314,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

304,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

'

'

'

1,304,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

304,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

900,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000,000

'

'

'

'

'

'

'

'

'

250,000,000

'

'

'

'

'

'

'

'

'

2016

'

'

'

814,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

354,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2017

'

'

'

104,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2018

'

'

'

653,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

403,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Thereafter

'

'

'

17,746,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,178,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,214,000,000

'

'

'

'

'

'

'

'

'

3,685,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,109,000,000

'

'

'

'

'

'

'

'

'

1,851,000,000

'

'

'

'

'

'

'

'

'

Long-term Debt (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

350,000,000

348,000,000

250,000,000

250,000,000

'

'

25,000,000

40,000,000

'

400,000,000

250,000,000

600,000,000

300,000,000

'

450,000,000

1,150,000,000

300,000,000

850,000,000

'

'

'

'

'

'

'

'

'

'

212,000,000

'

'

'

'

'

'

231,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

212,000,000

'

'

'

'

'

'

'

'

'

350,000,000

'

'

'

'

'

'

'

'

348,000,000

231,000,000

250,000,000

'

'

250,000,000

'

'

'

'

'

250,000,000

'

'

'

'

120,000,000

135,000,000

'

'

'

250,000,000

'

'

'

'

228,000,000

96,000,000

'

Stated interest rate

'

'

'

'

'

'

'

'

'

'

'

6.30%

8.05%

8.30%

4.75%

'

4.65%

4.65%

'

'

1.68%

1.68%

3.88%

3.88%

1.90%

3.40%

4.70%

'

5.90%

4.63%

2.04%

2.77%

'

'

'

'

'

'

'

'

'

'

4.60%

5.70%

'

'

'

'

'

'

'

'

'

'

4.32%

8.86%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.30%

'

'

5.70%

8.05%

8.30%

'

'

'

'

4.60%

'

8.86%

'

'

'

'

'

'

'

4.75%

'

'

'

'

'

'

'

'

'

'

4.65%

'

'

4.65%

'

'

'

'

'

4.65%

'

'

'

'

'

'

'

'

'

4.65%

'

'

'

'

'

'

'

Percentage of principal amount the remarketing dealer will pay if the REPS are purchased for remarketing

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate carrying value of property subject to lien

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,100,000,000

4,300,000,000

'

'

'

3,200,000,000

2,700,000,000

5,100,000,000

4,400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,100,000,000

4,300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

3,200,000,000

2,700,000,000

'

5,100,000,000

4,400,000,000

'

'

'

'

'

'

3,200,000,000

2,700,000,000

'

'

'

'

'

'

'

'

5,100,000,000

4,400,000,000

'

'

'

Principal amount that may be redeemed at a future date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

224,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

224,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earliest date the company may redeem the debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Feb-15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15-Feb-15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal amount that may be redeemed in whole or in part

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Oct-20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Oct-20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

321,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

321,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

294,000,000

'

'

'

'

'

'

'

'

'

27,000,000

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

604,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

604,000,000

'

'

'

'

'

'

'

'

'

280,000,000

'

'

'

'

'

'

'

'

'

324,000,000

Maximum number of days wherein interest rates reset

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'weekly or every 35 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'weekly or every 35 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'weekly or every 35 days

'

'

'

'

'

'

'

'

'

'weekly or every 35 days

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

368,000,000

225,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase (decrease) in principal due to inflation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

12,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal amount that may be put back to the issuer

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,200,000,000

3,800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from issuance of unsecured debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40,000,000

64,000,000

'

'

637,000,000

394,000,000

'

'

'

'

436,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of secured debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

345,000,000

'

246,000,000

246,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

345,000,000

'

'

'

'

'

'

'

'

'

'

246,000,000

'

'

246,000,000

'

'

'

'

'

246,000,000

'

'

'

'

'

'

'

'

'

246,000,000

'

'

'

'

'

'

'

Principal amount of debt exchanged

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

167,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

167,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest payments relating to debt extinguishment costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of senior notes

'

'

'

'

'

'

'

'

'

'

'

300,000,000

284,000,000

153,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

284,000,000

153,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Securities (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of common stock repurchased

'

'

'

2,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase of common stock due to the repurchase program

'

'

'

74,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock issuance date

'

'

'

30-Apr-12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares of PPL common stock issued

40,000,000

9,900,000

92,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional shares of common stock to be purchased by underwriters in a future period to cover over-allotments

'

591,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlement date of forward sale agreements

'

30-Apr-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Price per share of PPL common stock issued

$28.73

'

$25.30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total gross increase in equity from issuance of PPL common stock

'

'

2,328,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Underwriting discount related to equity offering

'

'

70,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Sale Agreement [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of common stock covered by a forward contract

'

9,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of counterparties involved in the sale agreements

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlement date of subsequent forward sale agreements

'

'

'

'

'

'

'

'

31-May-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares physically delivered relating to forward sale agreements

'

'

'

'

'

'

'

'

'

8,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares cash settled relating to forward sale agreements

'

'

'

'

'

'

'

'

591,000

1,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Initial forward price used to calculate the forward sale price

'

'

'

'

'

'

'

'

'

$27.02

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash settlement of equity forward agreements

'

'

'

-13,000,000

[9]

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net cash received on stock transaction

1,150,000,000

'

2,258,000,000

'

'

'

'

'

'

205,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Units [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity unit issuance date

'

'

'

'

'

'

'2011-04-01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of equity units sold (in units)

'

'

'

'

'

'

19,550,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated price per Equity Unit

'

'

'

'

'

'

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate value of Equity Units expected to be remarketed

'

'

'

'

'

'

978,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from issuance of Equity Units

'

'

'

'

'

'

948,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Underwriting discount related to issuance of equity units

'

'

'

'

'

'

30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Undivided beneficial ownership in debt initially associated with Equity Units

'

'

'

'

'

'

'

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal amount of PPL Capital Funding Junior Subordinated Notes that an Equity Unit holder has an interest

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dollar value of PPL common stock that the holder of Equity Unit is required to purchase

'

'

'

'

'

'

'

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of trading days included in the calculation of average VWAP

'

'

'

'

'

'

'

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum average VWAP (in dollars per share)

'

'

'

'

'

'

'

$30.99

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

The number of shares of PPL common stock to be issued under each purchase contract at maximum VWAP

'

'

'

'

'

'

'

1.6133

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total shares of PPL common stock to be issued under Purchase Contract at maximum VWAP or higher

'

'

'

'

'

'

'

31,540,015

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Range of average VWAP in middle tier of Purchase Contract settlement calculation

'

'

'

'

'

'

'

'less than approximately $30.99 but greater than $25.30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum average VWAP (in dollars per share)

'

'

'

'

'

'

'

$25.30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of PPL common stock to be issued to each Purchase Contract holder at minimum VWAP

'

'

'

'

'

'

'

1.9763

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total shares of PPL common stock to be issued under Purchase Contract at minimum VWAP or lower

'

'

'

'

'

'

'

38,636,665

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum equity unit purchase contract component settlement date

'

'

'

'

'

'

'

'2014-05-01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of PPL common stock to be issued to each holder if settled early

'

'

'

'

'

'

'

1.6133

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum number of shares of PPL common stock to be issued to settle the make whole provisions of the Purchase Contract component of the Equity Units

'

'

'

'

'

'

'

1,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate on Purchase Contract component of Equity Units

'

'

'

'

'

'

'

4.43%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate on Purchase Contract component of Equity Units on deferred contract adjustment payments

'

'

'

'

'

'

'

8.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of tranches that will result from an expected remarketing

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

Minimum aggregate principal amount of each tranche when remarketing occurs

'

'

'

'

'

'

'

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

Minimum percentage of a tranche of the total when a remarketing occurs

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

Number of tranches that will mature on or about third anniversary of the remarketing

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

'

'

'

'

'

'

'

'

Present value of the Purchase Contract component of the Equity Units

'

'

'

'

'

$123,000,000

'

'

'

'

'

'

'

'

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'

'

'

'

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'

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'

'

'

'

'

'

'

'

'

'

The term, in years, over which the accretion will occur

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

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'

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'

'

'

[1]

Includes $300 million of 5.70% REset Put Securities due 2035 (REPS). The REPS bear interest at a rate of 5.70% per annum to, but excluding, October 15, 2015 (Remarketing Date). The REPS are required to be put by existing holders on the Remarketing Date either for (a) purchase and remarketing by a designated remarketing dealer or (b) repurchase by PPL Energy Supply. If the remarketing dealer elects to purchase the REPS for remarketing, it will purchase the REPS at 100% of the principal amount, and the REPS will bear interest on and after the Remarketing Date at a new fixed rate per annum determined in the remarketing. PPL Energy Supply has the right to terminate the remarketing process. If the remarketing is terminated at the option of PPL Energy Supply or under certain other circumstances, including the occurrence of an event of default by PPL Energy Supply under the related indenture or a failed remarketing for certain specified reasons, PPL Energy Supply will be required to pay the remarketing dealer a settlement amount as calculated in accordance with the related remarketing agreement.

[2]

Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $5.1 billion and $4.3 billion at December 31, 2013 and 2012. Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $3.2 billion and $2.7 billion at December 31, 2013 and December 31, 2012. Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $5.1 billion and $4.4 billion at December 31, 2013 and December 31, 2012.

[3]

Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amount, 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 (c) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate. At December 31, 2013, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $321 million for LKE, comprised of $294 million and $27 million for LG&E and KU. At December 31, 2013, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $604 million for LKE, comprised of $280 million and $324 million for LG&E and KU. 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 process. 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 variable rate tax-exempt revenue bonds totaling $348 million at December 31, 2013 ($120 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.

[4]

Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (c) above. This amount includes $224 million that may be redeemed 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.

[5]

2012 includes lease financing consolidated through a VIE which was repaid in 2013. See Note 22 for additional information.

[6]

Includes £3.8 billion ($6.2 billion at December 31, 2013) of notes that may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the notes are withdrawn by any of the rating agencies (Moody's, S&P or Fitch) or reduced to a non-investment grade rating of Ba1 or BB+ in connection with a restructuring event which includes the loss of, or a material adverse change to, the distribution licenses under which the issuer operates.

[7]

Includes £225 million ($368 million at December 31, 2013) of notes that may be redeemed, in total but not in part, on December 21, 2026, at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. Government bond.

[8]

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 principal amounts from 2012 to 2013 was an increase of approximately £12 million ($20 million) resulting from inflation. In addition, this amount includes £225 million ($368 million at December 31, 2013) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026, at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nominated U.K. government bond.

[9]

See Note 7 for additional information.

Financing_Activities_Distribut

Financing Activities (Distributions and Capital Contributions) (Details) (USD $)

1 Months Ended

3 Months Ended

12 Months Ended

Feb. 28, 2014

Nov. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Distributions and Capital Contributions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Quarterly common stock dividend declaration date

'2014-02

'2013-11

'

'

'

'

'

'

'

'

'

'

'

Dividend payable date of quarterly common stock dividend

1-Apr-14

2-Jan-14

'

'

'

'

'

'

'

'

'

'

'

Current quarterly common stock dividend (in dollars per share)

'

$0.37

$0.37

[1],[2]

$0.37

[1],[2]

$0.37

[1],[2]

$0.37

[1],[2]

$0.36

[1],[2]

$0.36

[1],[2]

$0.36

[1],[2]

$0.36

[1],[2]

$1.47

$1.44

$1.40

Quarterly common stock dividend (in dollars per share)

$0.37

'

'

'

'

'

'

'

'

'

'

'

'

Annualized current quarterly common stock dividend (in dollars per share)

$1.49

$1.47

'

'

'

'

'

'

'

'

'

'

'

Restricted net assets at end of period

'

'

$2,500,000,000

'

'

'

'

'

'

'

$2,500,000,000

'

'

Unrestricted assets at the end of period

'

'

2,500,000,000

'

'

'

'

'

'

'

2,500,000,000

'

'

Minimum adjusted equity to total capitalization in order to pay dividends

'

'

'

'

'

'

'

'

'

'

30.00%

'

'

PPL Energy Supply LLC [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions and Capital Contributions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends/distributions paid to parent/member

'

'

'

'

'

'

'

'

'

'

408,000,000

787,000,000

316,000,000

Capital contributions received from parent/member

'

'

'

'

'

'

'

'

'

'

1,577,000,000

563,000,000

461,000,000

PPL Electric Utilities Corp [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions and Capital Contributions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends/distributions paid to parent/member

'

'

'

'

'

'

'

'

'

'

127,000,000

95,000,000

92,000,000

Capital contributions received from parent/member

'

'

'

'

'

'

'

'

'

'

205,000,000

150,000,000

100,000,000

LG And E And KU Energy LLC [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions and Capital Contributions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends/distributions paid to parent/member

'

'

'

'

'

'

'

'

'

'

254,000,000

155,000,000

533,000,000

Capital contributions received from parent/member

'

'

'

'

'

'

'

'

'

'

243,000,000

'

'

Restricted net assets at end of period

'

'

2,500,000,000

'

'

'

'

'

'

'

2,500,000,000

'

'

Unrestricted assets at the end of period

'

'

2,500,000,000

'

'

'

'

'

'

'

2,500,000,000

'

'

Minimum adjusted equity to total capitalization in order to pay dividends

'

'

'

'

'

'

'

'

'

'

30.00%

'

'

Louisville Gas And Electric Co [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions and Capital Contributions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends/distributions paid to parent/member

'

'

'

'

'

'

'

'

'

'

99,000,000

75,000,000

83,000,000

Capital contributions received from parent/member

'

'

'

'

'

'

'

'

'

'

86,000,000

'

'

Restricted net assets at end of period

'

'

1,000,000,000

'

'

'

'

'

'

'

1,000,000,000

'

'

Unrestricted assets at the end of period

'

'

1,000,000,000

'

'

'

'

'

'

'

1,000,000,000

'

'

Minimum adjusted equity to total capitalization in order to pay dividends

'

'

'

'

'

'

'

'

'

'

30.00%

'

'

Kentucky Utilities Co [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions and Capital Contributions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends/distributions paid to parent/member

'

'

'

'

'

'

'

'

'

'

124,000,000

100,000,000

124,000,000

Capital contributions received from parent/member

'

'

'

'

'

'

'

'

'

'

157,000,000

'

'

Restricted net assets at end of period

'

'

1,500,000,000

'

'

'

'

'

'

'

1,500,000,000

'

'

Unrestricted assets at the end of period

'

'

$1,500,000,000

'

'

'

'

'

'

'

$1,500,000,000

'

'

Minimum adjusted equity to total capitalization in order to pay dividends

'

'

'

'

'

'

'

'

'

'

30.00%

'

'

[1]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[2]

PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.

Acquisitions_Development_and_D1

Acquisitions, Development and Divestures (Details) (USD $)

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jan. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Jan. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jan. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

MW

Cane Run Unit 7 [Member]

Cane Run And Green River Plants [Member]

Tyrone Plant [Member]

Haefling Plant [Member]

Future Capacity [Member]

Green River Plant [Member]

Solar Generation Facility [Member]

Holtwood Hydroelectric Plant Expansion [Member]

Rainbow Hydroelectric Plant Expansion [Member]

Rainbow Hydroelectric Plant Expansion [Member]

Proposed Bell Bend Nuclear Unit [Member]

Proposed Bell Bend Nuclear Unit [Member]

Susquehanna Roseland Transmission Line [Member]

Northeast Pocono Reliability Project [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Integer

MW

MW

MW

MW

MW

MW

MW

Integer

mi

mi

MW

Holtwood Hydroelectric Plant Expansion [Member]

Rainbow Hydroelectric Plant Expansion [Member]

Rainbow Hydroelectric Plant Expansion [Member]

Proposed Bell Bend Nuclear Unit [Member]

Proposed Bell Bend Nuclear Unit [Member]

Susquehanna Roseland Transmission Line [Member]

Rainbow Hydroelectric Plant Expansion [Member]

Susquehanna Roseland Transmission Line [Member]

Northeast Pocono Reliability Project [Member]

Cane Run Unit 7 [Member]

Cane Run And Green River Plants [Member]

Tyrone Plant [Member]

Haefling Plant [Member]

Future Capacity [Member]

Green River Plant [Member]

Solar Generation Facility [Member]

Cane Run Unit 7 [Member]

Cane Run And Green River Plants [Member]

Green River Plant [Member]

Solar Generation Facility [Member]

Cane Run Unit 7 [Member]

Cane Run And Green River Plants [Member]

Tyrone Plant [Member]

Haefling Plant [Member]

Green River Plant [Member]

Solar Generation Facility [Member]

MW

kV

Integer

Integer

MW

MW

Integer

mi

Integer

MW

MW

MW

MW

MW

MW

Integer

MW

MW

MW

MW

MW

MW

MW

kV

mi

Integer

MW

Integer

Development Projects [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Planned capacity expansion (in MW)

'

'

'

'

'

'

'

700

700

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

700

700

10

'

'

700

10

'

'

'

'

700

10

Completed capacity expansion (in MW)

'

'

'

'

'

'

'

'

'

'

125

'

63

'

'

'

'

'

'

'

125

'

63

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expected capital cost of an expansion project

'

'

'

$600,000,000

'

'

'

'

$700,000,000

$36,000,000

'

'

'

'

'

'

$335,000,000

'

'

'

'

'

'

'

'

'

'

'

$335,000,000

$600,000,000

'

'

'

'

$700,000,000

$36,000,000

$600,000,000

'

$700,000,000

$36,000,000

$600,000,000

'

'

'

$700,000,000

$36,000,000

Ownership percentage in a jointly owned plant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22.00%

'

40.00%

36.00%

78.00%

'

'

'

60.00%

64.00%

Number of plants anticipated to retire based on stricter EPA regulations or new construction

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

5

'

'

'

5

'

'

'

'

Capacity of plants anticipated to be retired (in MW)

'

'

'

'

724

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

724

'

'

'

'

'

'

724

'

'

'

724

'

'

'

'

Capacity of plants retired (in MW)

'

'

'

'

'

71

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

71

12

'

'

'

'

'

'

'

'

'

71

12

'

'

Cumulative deferred investments tax credits recorded

60,000,000

'

'

'

'

'

'

'

'

'

117,000,000

'

60,000,000

'

'

'

'

'

'

'

117,000,000

'

60,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Treasury grants approved, accepted and to be received in lieu of tax credits

'

'

'

'

'

'

'

'

'

'

'

56,000,000

'

'

'

'

'

'

'

'

'

56,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cumulative deferred investments tax credits to be recaptured

'

'

'

'

'

'

'

'

'

'

'

60,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of applicants still active in DOE nuclear guarantee program

'

'

'

'

'

'

'

'

'

'

'

'

'

8

'

'

'

'

'

'

'

'

'

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of applicants that submitted loan guarantees to the DOE

'

'

'

'

'

'

'

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current appropriated federal loan guarantees for nuclear projects

'

'

'

'

'

'

'

'

'

'

'

'

'

18,500,000,000

'

'

'

'

'

'

'

'

'

18,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum number of projects the DOE is expected to finance

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount currently authorized by Board of Directors to spend on Bell Bend COLA

'

'

'

'

'

'

'

'

'

'

'

'

'

224,000,000

'

'

'

'

'

'

'

'

'

224,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized costs associated with licensing efforts

'

'

'

'

'

'

'

'

'

'

'

'

'

173,000,000

154,000,000

'

'

'

'

'

'

'

'

173,000,000

154,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total length (in miles) of the expansion project

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150

58

'

'

'

'

'

'

'

'

'

'

150

58

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capacity (in kilovolts) of a transmission line

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500

230

'

'

'

'

'

'

'

'

'

'

500

230

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share of the expected capital cost of an expansion project when the company has a joint ownership interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

630,000,000

'

'

'

'

'

'

'

'

'

'

'

630,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Project costs capitalized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

377,000,000

'

'

'

'

'

'

'

'

'

377,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total length (in miles) of the expansion project to be routed through Pennsylvania

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101

'

'

'

'

'

'

'

'

'

'

'

101

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of new substations included in request

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adder to the return on equity incentive denied in ratemaking request (in basis points)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100

'

'

'

'

'

'

'

'

'

'

'

100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Zoning petitions to be approved

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other - Montana Transactions (Numeric) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capacity of facilities to be sold (in MW)

633

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

633

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Agreed upon sales price for disposal of hydroelectric facilities owned by PPL Montana

900,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

900,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of hydroelectric facilities owned by PPL Montana to be sold

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on lease termination

-697,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-697,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on sale-leaseback termination, after-tax

413,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

413,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment on lease termination

$271,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$271,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Discontinued Operations (Numeric) [Abstract]	'	'	'
Proceeds from the sale of certain non-core generation facilities	'	'	$381
PPL Energy Supply LLC [Member]	'	'	'
Discontinued Operations (Numeric) [Abstract]	'	'	'
Proceeds from the sale of certain non-core generation facilities	'	'	$381

Business_Acquisitions_Details

Business Acquisitions (Details) (USD $)

12 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2012

Dec. 31, 2012

Apr. 30, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2012

Dec. 31, 2012

Severance Compensation [Member]

Severance Compensation [Member]

Early Retirement Deficiency Costs Under Applicable Pension Plans [Member]

Early Retirement Deficiency Costs Under Applicable Pension Plans [Member]

Separation Benefits [Member]

Separation Benefits [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

Ironwood [Member]

Ironwood [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

WPD Midlands [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

One Time Termination Benefits Member Specific Employee Class [Member]

Severance Compensation [Member]

Severance Compensation [Member]

Early Retirement Deficiency Costs Under Applicable Pension Plans [Member]

Outplacement Services [Member]

Separation Benefits [Member]

Separation Benefits [Member]

Integer

Integer

2011 Bridge Facility Costs [Member]

Foreign Currency Loss On 2011 Bridge Facility [Member]

Net Hedge Gains Associated With 2011 Bridge Facility [Member]

Hedge Ineffectiveness [Member]

UK Stamp Duty Tax [Member]

Seperation Benefits [Member]

Other Acquisition Related Adjustments [Member]

PPL Capital Funding [Member]

PPL WEM [Member]

United Kingdom Regulated [Member]

Ironwood [Member]

Ironwood [Member]

Integer

Foreign Currency Loss On 2011 Bridge Facility [Member]

Foreign Currency Loss On 2011 Bridge Facility [Member]

Integer

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13-Apr-12

'

1-Apr-11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13-Apr-12

'

Number of units purchased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

Number of regulated distribution networks operated by WPD Midlands

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of end users serviced by purchased company

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Consideration Paid for Acquisition [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate enterprise consideration

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$326,000,000

'

$6,600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$326,000,000

'

Less: Fair value of long-term debt outstanding assumed through consolidation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

258,000,000

[1]

'

800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

258,000,000

[1]

'

Total cash consideration paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Less: Funds used to repay pre-acquisition affiliate indebtedness

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Plus: Restricted cash debt service reserves

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,000,000

'

Cash consideration paid for equity interests (including working capital adjustments)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85,000,000

'

4,100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85,000,000

'

Original amount outstanding of debt assumed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

226,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

226,000,000

'

Interest rate of debt assumed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.86%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.86%

'

Maturity date of debt assumed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Dec-25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Dec-25

'

Debt service reserve loans

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,000,000

'

Fair value adjustment related to debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24,000,000

'

Business Acquisition, Purchase Price Allocation [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

PP&E

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

505,000,000

'

4,900,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

505,000,000

Intangible assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other noncurrent assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-400,000,000

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

PPL WEM affiliate indebtedness

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long term debt (current and noncurrent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-258,000,000

[4]

'

-800,000,000

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-258,000,000

[4]

Tolling agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-170,000,000

[5]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-170,000,000

[5]

Other net assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,000,000

[4]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,000,000

[4]

Other noncurrent liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-700,000,000

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net identifiable assets acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85,000,000

'

1,700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85,000,000

Goodwill

4,225,000,000

4,158,000,000

4,114,000,000

[6]

'

'

'

'

'

'

3,143,000,000

[6]

3,076,000,000

[6]

3,032,000,000

[6]

'

'

'

'

'

'

'

'

'

'

2,400,000,000

'

'

'

'

'

'

'

'

'

2,400,000,000

86,000,000

86,000,000

'

'

'

Net assets acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gross contractual obligation of accounts receivable acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

122,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Pro Forma Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

790,000,000

'

'

'

'

'

Net Income (Loss) Attributable to PPL Shareowners

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

137,000,000

'

'

'

'

'

Operating Revenues - PPL consolidated pro forma (unaudited)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,140,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss) Attributable to PPL Shareowners - PPL consolidated pro forma (unaudited)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Pro Forma Information, Pre-tax Nonrecurring Credits (Expenses) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

-1,006,000,000

-961,000,000

-898,000,000

'

'

'

'

'

'

-425,000,000

-421,000,000

-391,000,000

'

'

'

'

'

'

'

'

'

'

'

-44,000,000

[7]

'

'

-12,000,000

[8]

'

'

'

'

'

'

-171,000,000

-168,000,000

-174,000,000

'

'

Other Income (Expense) - net

-23,000,000

-39,000,000

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-57,000,000

[9]

55,000,000

[10]

'

-21,000,000

[11]

'

'

'

'

'

30,000,000

18,000,000

23,000,000

'

'

Other operation and maintenance

-2,825,000,000

-2,835,000,000

-2,667,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-102,000,000

[12]

'

'

'

'

-1,072,000,000

-1,041,000,000

-929,000,000

'

'

Other Income (Expense) - net and Other operation and maintenance

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-77,000,000

[13]

'

'

'

'

'

'

'

'

Foreign currency loss

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-42,000,000

-15,000,000

'

'

'

'

'

'

Separation Benefits - U.K. Regulated Segment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of employees terminated

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

729

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expected costs to be incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

61,000,000

'

46,000,000

'

108,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Costs incurred

'

'

'

13,000,000

48,000,000

2,000,000

45,000,000

15,000,000

93,000,000

'

'

'

9,000,000

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued severance at beginning of period

'

'

'

'

'

'

'

'

'

'

'

'

'

21,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Severance compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

13,000,000

48,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Severance paid

'

'

'

'

'

'

'

'

'

'

'

'

'

34,000,000

27,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued severance at end of period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$21,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

The long-term debt assumed through consolidation consisted of $226 million aggregate principal amount of 8.857% senior secured bonds to be fully repaid by December 31, 2025, plus $8 million of debt service reserve loans, and a $24 million fair value adjustment. See Note 7 for information on the February 2013 exchange of a portion of long-term debt assumed through consolidation.

[2]

Includes gross contractual amount of the accounts receivable acquired of $122 million, which approximates fair value.

[3]

Represents non-cash activity excluded from the 2011 Statement of Cash Flows.

[4]

Represents non-cash activity excluded from the 2012 Statement of Cash Flows.

[5]

Prior to the acquisition, PPL EnergyPlus had recorded primarily an intangible asset, which represented its rights to and the related accounting for the tolling agreement with PPL Ironwood, LLC. On the acquisition date, PPL Ironwood, LLC recorded a liability, recognized at fair value, for its obligation to PPL EnergyPlus. The tolling agreement assets of PPL EnergyPlus and the tolling agreement liability of PPL Ironwood, LLC eliminate in consolidation for PPL and PPL Energy Supply as a result of the acquisition, and therefore the agreement is considered effectively settled. The difference between the tolling agreement assets and liability resulted in an insignificant loss on the effective settlement of the agreement.

[6]

There were no accumulated impairment losses related to goodwill.

[7]

The 2011 Bridge Facility costs, primarily commitment and structuring fees, were incurred to establish a bridge facility for purposes of funding the WPD Midlands acquisition purchase price.

[8]

The hedge ineffectiveness includes a combination of ineffectiveness associated with closed out interest rate swaps and a charge recorded as a result of certain interest rate swaps failing hedge effectiveness testing, both associated with the acquisition financing.

[9]

The 2011 Bridge Facility was denominated in GBP. The amount includes a $42 million foreign currency loss on PPL Capital Funding's repayment of its 2011 Bridge Facility borrowing and a $15 million foreign currency loss associated with proceeds received on the U.S. dollar-denominated senior notes issued by PPL WEM in April 2011 that were used to repay a portion of PPL WEM's borrowing under the 2011 Bridge Facility.

[10]

The repayment of borrowings on the 2011 Bridge Facility was economically hedged to mitigate the effects of changes in foreign currency exchange rates with forward contracts to purchase GBP, which resulted in net hedge gains.

[11]

The U.K. stamp duty tax represents a tax on the transfer of ownership of property in the U.K. incurred in connection with the acquisition.

[12]

See "Separation Benefits - U.K. Regulated Segment" above.

[13]

Primarily includes acquisition-related advisory, accounting and legal fees recorded in "Other Income (Expense) - net" and contract termination costs, rebranding costs and relocation costs recorded in "Other operation and maintenance."

Leases_Details

Leases (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jan. 31, 2014
Lessee Transactions [Line Items]	'	'	'	'
Percentage of leasehold interest in Colstrip Units 1 and 2	'	50.00%	'	'
Percentage of leasehold interest in Colstrip Unit 3	'	30.00%	'	'
Operating Leases - Kerr Dam (Numeric) [Abstract]	'	'	'	'
Amount to be included in the Kerr Dam conveyance price for tangible assets decided by arbitrator	'	'	'	$17
Amount requested to be included in Kerr Dam conveyance price for environmental mitigation costs to be decided by arbitrator	'	'	'	32
Rent - Operating Leases (Details) [Abstract]	'	'	'	'
Operating leases, rent expense	111	116	109	'
Operating leases, future minimum rental payments due (Details) [Abstract]	'	'	'	'
2014	59	'	'	'
2015	47	'	'	'
2016	23	'	'	'
2017	18	'	'	'
2018	12	'	'	'
Thereafter	42	'	'	'
Total	201	'	'	'
PPL Energy Supply LLC [Member]	'	'	'	'
Lessee Transactions [Line Items]	'	'	'	'
Percentage of leasehold interest in Colstrip Units 1 and 2	'	50.00%	'	'
Percentage of leasehold interest in Colstrip Unit 3	'	30.00%	'	'
Operating Leases - Kerr Dam (Numeric) [Abstract]	'	'	'	'
Amount to be included in the Kerr Dam conveyance price for tangible assets decided by arbitrator	'	'	'	17
Amount requested to be included in Kerr Dam conveyance price for environmental mitigation costs to be decided by arbitrator	'	'	'	32
Rent - Operating Leases (Details) [Abstract]	'	'	'	'
Operating leases, rent expense	55	62	84	'
Operating leases, future minimum rental payments due (Details) [Abstract]	'	'	'	'
2014	31	'	'	'
2015	25	'	'	'
2016	11	'	'	'
2017	10	'	'	'
2018	3	'	'	'
Thereafter	3	'	'	'
Total	83	'	'	'
LG And E And KU Energy LLC [Member]	'	'	'	'
Rent - Operating Leases (Details) [Abstract]	'	'	'	'
Operating leases, rent expense	18	18	18	'
Operating leases, future minimum rental payments due (Details) [Abstract]	'	'	'	'
2014	16	'	'	'
2015	13	'	'	'
2016	9	'	'	'
2017	6	'	'	'
2018	6	'	'	'
Thereafter	29	'	'	'
Total	79	'	'	'
Louisville Gas And Electric Co [Member]	'	'	'	'
Rent - Operating Leases (Details) [Abstract]	'	'	'	'
Operating leases, rent expense	7	7	7	'
Operating leases, future minimum rental payments due (Details) [Abstract]	'	'	'	'
2014	6	'	'	'
2015	5	'	'	'
2016	4	'	'	'
2017	2	'	'	'
2018	2	'	'	'
Thereafter	12	'	'	'
Total	31	'	'	'
Kentucky Utilities Co [Member]	'	'	'	'
Rent - Operating Leases (Details) [Abstract]	'	'	'	'
Operating leases, rent expense	10	10	10	'
Operating leases, future minimum rental payments due (Details) [Abstract]	'	'	'	'
2014	10	'	'	'
2015	8	'	'	'
2016	5	'	'	'
2017	4	'	'	'
2018	3	'	'	'
Thereafter	15	'	'	'
Total	$45	'	'	'

StockBased_Compensation_Detail

Stock-Based Compensation (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Aggregate disclosures [Abstract]	'		'	'
Compensation expense	$50,000,000		$47,000,000	$33,000,000
All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Unrecognized compensation expense	33,000,000		'	'
Weighted-average period for recognition	1.9		'	'
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)	2,503,770		'	'
Granted (in shares)	1,307,951		'	'
Vested (in shares)	-638,421		'	'
Forfeited (in shares)	-32,700		'	'
Nonvested, end of period (in shares)	3,140,600		2,503,770	'
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)	$27.73		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$30.30		$28.35	$25.25
Weighted-average grant date fair value per share, vested (in dollars per share)	($29.19)		'	'
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($28.61)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$28.50		$27.73	'
Total fair value of units vested during the period	19,000,000		27,000,000	19,000,000
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
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)	594,203		'	'
Granted (in shares)	348,495		'	'
Forfeited (in shares)	-149,499		'	'
Nonvested, end of period (in shares)	793,199		594,203	'
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)	$31.14		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$34.15		$31.41	$29.67
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($32.63)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$32.19		$31.14	'
Period over which performance units fair value is recognized (in years)	'3		'3	'3
Maximum payout percentage of target award	200.00%		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
Risk-free interest rate	0.36%		0.30%	1.00%
Expected option life (in years)	3		3	3
Expected stock volatility	15.50%		19.30%	23.40%
All Plans [Member] | Stock Options [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Cash received from exercise of stock options	31,000,000		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Risk-free interest rate	1.15%		1.13%	2.34%
Expected option life (in years)	6.48		6.17	5.71
Expected stock volatility	18.50%		20.60%	21.60%
Dividend yield	5.00%		5.00%	5.93%
Stock option activity [Roll Forward]	'		'	'
Outstanding at beginning of period (in shares)	9,134,545		'	'
Granted (in shares)	3,383,630		'	'
Exercised (in shares)	-1,136,693		'	'
Outstanding at end of period (in shares)	11,381,482		9,134,545	'
Stock options - additional disclosures [Abstract]	'		'	'
Period that performance goals are evaluated (in years)	'3		'	'
Period after which employee stock options become exercisable in installments (in years)	'1		'	'
Period after which, employee stock options expire (in years)	'10		'	'
Weighted-average exercise price per share at beginning of period (in dollars per share)	$30.36		'	'
Weighted average exercise price per share, granted (in dollars per share)	$29.56		'	'
Weighted average exercise price per share, exercised (in dollars per share)	$27.13		'	'
Weighted average exercise price per share at end of period (in dollars per share)	$30.45		$30.36	'
Weighted average remaining contractual term (in years)	6.6		'	'
Aggregate total intrinsic value	15,000,000		'	'
Options exercisable at end of period (in shares)	6,415,615		'	'
Weighted average exercise price, options exercisable at end of period (in dollars per share)	$31.66		'	'
Weighted average remaining contractual term, options exercisable at end of period (in years)	5		'	'
Aggregate total intrinsic value, options exercisable at end of period	8,000,000		'	'
Weighted average grant date fair value of options granted (in dollars per share)	$2.18		$2.48	$2.47
Total intrinsic value of stock options exercised	6,000,000		'	'
All Plans [Member] | All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Compensation expense	52,000,000		49,000,000	36,000,000
Income tax benefit	22,000,000		20,000,000	15,000,000
Incentive Compensation Plan [Member]	'		'	'
Stock-Based Compensation [Line Items]	'		'	'
Maximum number of shares approved for awards under the plan (in shares)	15,769,431	[1]	'	'
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%	[1]	'	'
Annual grant limit options (in shares)	3,000,000	[1]	'	'
Annual grant limit for individual participants - performance based awards (in shares)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
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		'	'
Stock Incentive Plan [Member]	'		'	'
Stock-Based Compensation [Line Items]	'		'	'
Period after grant, employee stock options expire upon retirement (in years)	10		'	'
Period after which, employee stock options expire upon retirement (in years)	5		'	'
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	'		'	'
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)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
PPL Energy Supply LLC [Member] | All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Unrecognized compensation expense	13,000,000		'	'
Weighted-average period for recognition	2		'	'
PPL Energy Supply 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)	1,060,686		'	'
Transferred (in shares)	3,820		'	'
Granted (in shares)	527,440		'	'
Vested (in shares)	-236,382		'	'
Forfeited (in shares)	-12,160		'	'
Nonvested, end of period (in shares)	1,343,404		1,060,686	'
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)	$27.95		'	'
Weighted-average grant date fair value per share, transferred (in dollars per share)	$27.31		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$30.42		$28.29	$25.14
Weighted-average grant date fair value per share, vested (in dollars per share)	($29.10)		'	'
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($29.04)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$28.71		$27.95	'
Total fair value of units vested during the period	7,000,000		6,000,000	6,000,000
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
PPL Energy Supply 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)	124,189		'	'
Granted (in shares)	74,614		'	'
Forfeited (in shares)	-28,194		'	'
Nonvested, end of period (in shares)	170,609		124,189	'
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)	$31.26		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$34.29		$31.40	$29.68
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($33.47)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$32.22		$31.26	'
Period over which performance units fair value is recognized (in years)	'3		'3	'3
Maximum payout percentage of target award	200.00%		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
Risk-free interest rate	0.36%		0.30%	1.00%
Expected option life (in years)	3		3	3
Expected stock volatility	15.50%		19.30%	23.40%
PPL Energy Supply LLC [Member] | All Plans [Member] | Stock Options [Member]	'		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Risk-free interest rate	1.15%		1.13%	2.34%
Expected option life (in years)	6.48		6.17	5.71
Expected stock volatility	18.50%		20.60%	21.60%
Dividend yield	5.00%		5.00%	5.93%
Stock option activity [Roll Forward]	'		'	'
Outstanding at beginning of period (in shares)	2,265,123		'	'
Transferred (in shares)	88,546		'	'
Granted (in shares)	713,030		'	'
Exercised (in shares)	-221,363		'	'
Outstanding at end of period (in shares)	2,845,336		2,265,123	'
Stock options - additional disclosures [Abstract]	'		'	'
Period that performance goals are evaluated (in years)	'3		'	'
Period after which employee stock options become exercisable in installments (in years)	'1		'	'
Period after which, employee stock options expire (in years)	'10		'	'
Weighted-average exercise price per share at beginning of period (in dollars per share)	$30.45		'	'
Weighted average exercise price per share, transferred (in dollars per share)	$25.67		'	'
Weighted average exercise price per share, granted (in dollars per share)	$29.66		'	'
Weighted average exercise price per share, exercised (in dollars per share)	$25.76		'	'
Weighted average exercise price per share at end of period (in dollars per share)	$30.47		$30.45	'
Weighted average remaining contractual term (in years)	6.2		'	'
Aggregate total intrinsic value	4,000,000		'	'
Options exercisable at end of period (in shares)	1,747,842		'	'
Weighted average exercise price, options exercisable at end of period (in dollars per share)	$31.48		'	'
Weighted average remaining contractual term, options exercisable at end of period (in years)	4.6		'	'
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)	$2.19		$2.51	$2.47
PPL Energy Supply LLC [Member] | All Plans [Member] | All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Compensation expense	27,000,000		23,000,000	16,000,000
Income tax benefit	11,000,000		10,000,000	6,000,000
PPL Energy Supply LLC [Member] | Incentive Compensation Plan [Member]	'		'	'
Stock-Based Compensation [Line Items]	'		'	'
Maximum number of shares approved for awards under the plan (in shares)	15,769,431	[1]	'	'
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%	[1]	'	'
Annual grant limit options (in shares)	3,000,000	[1]	'	'
Annual grant limit for individual participants - performance based awards (in shares)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
PPL Energy Supply 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		'	'
PPL Energy Supply LLC [Member] | Stock Incentive Plan [Member]	'		'	'
Stock-Based Compensation [Line Items]	'		'	'
Period after grant, employee stock options expire upon retirement (in years)	10		'	'
Period after which, employee stock options expire upon retirement (in years)	5		'	'
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	'		'	'
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 Energy Supply 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)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
PPL Electric Utilities Corp [Member] | All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Unrecognized compensation expense	3,000,000		'	'
Weighted-average period for recognition	2		'	'
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)	261,228		'	'
Transferred (in shares)	-5,810		'	'
Granted (in shares)	108,990		'	'
Vested (in shares)	-94,008		'	'
Forfeited (in shares)	-4,850		'	'
Nonvested, end of period (in shares)	265,550		261,228	'
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)	$27.30		'	'
Weighted-average grant date fair value per share, transferred (in dollars per share)	$27.48		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$30.55		$28.51	$25.09
Weighted-average grant date fair value per share, vested (in dollars per share)	($28.41)		'	'
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($28.61)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$28.22		$27.30	'
Total fair value of units vested during the period	3,000,000		2,000,000	2,000,000
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
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)	26,083		'	'
Granted (in shares)	18,666		'	'
Forfeited (in shares)	-6,539		'	'
Nonvested, end of period (in shares)	38,210		26,083	'
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)	$31.10		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$33.97		$31.37	$29.57
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($32.78)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$32.22		$31.10	'
Period over which performance units fair value is recognized (in years)	'3		'3	'3
Maximum payout percentage of target award	200.00%		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
Risk-free interest rate	0.36%		0.30%	1.00%
Expected option life (in years)	3		3	3
Expected stock volatility	15.50%		19.30%	23.40%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Stock Options [Member]	'		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Risk-free interest rate	1.15%		1.13%	2.34%
Expected option life (in years)	6.48		6.17	5.71
Expected stock volatility	18.50%		20.60%	21.60%
Dividend yield	5.00%		5.00%	5.93%
Stock option activity [Roll Forward]	'		'	'
Outstanding at beginning of period (in shares)	340,530		'	'
Granted (in shares)	191,670		'	'
Outstanding at end of period (in shares)	532,200		340,530	'
Stock options - additional disclosures [Abstract]	'		'	'
Period that performance goals are evaluated (in years)	'3		'	'
Period after which employee stock options become exercisable in installments (in years)	'1		'	'
Period after which, employee stock options expire (in years)	'10		'	'
Weighted-average exercise price per share at beginning of period (in dollars per share)	$30.35		'	'
Weighted average exercise price per share, granted (in dollars per share)	$29.49		'	'
Weighted average exercise price per share at end of period (in dollars per share)	$30.04		$30.35	'
Weighted average remaining contractual term (in years)	7.1		'	'
Aggregate total intrinsic value	1,000,000		'	'
Options exercisable at end of period (in shares)	260,950		'	'
Weighted average exercise price, options exercisable at end of period (in dollars per share)	$31.24		'	'
Weighted average remaining contractual term, options exercisable at end of period (in years)	5.5		'	'
Weighted average grant date fair value of options granted (in dollars per share)	$2.19		$2.50	$2.47
PPL Electric Utilities Corp [Member] | All Plans [Member] | All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Compensation expense	10,000,000		11,000,000	8,000,000
Income tax benefit	4,000,000		4,000,000	3,000,000
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)	15,769,431	[1]	'	'
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%	[1]	'	'
Annual grant limit options (in shares)	3,000,000	[1]	'	'
Annual grant limit for individual participants - performance based awards (in shares)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
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		'	'
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		'	'
Period after which, employee stock options expire upon retirement (in years)	5		'	'
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	'		'	'
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)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
LG And E And KU Energy LLC [Member] | All Awards [Member]	'		'	'
Aggregate disclosures [Abstract]	'		'	'
Unrecognized compensation expense	2,000,000		'	'
Weighted-average period for recognition	1.7		'	'
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)	139,640		'	'
Granted (in shares)	127,293		'	'
Vested (in shares)	-35,380		'	'
Nonvested, end of period (in shares)	231,553		139,640	'
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)	$28.34		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$30		$28.34	'
Weighted-average grant date fair value per share, vested (in dollars per share)	($28.87)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$29.17		$28.34	'
Total fair value of units vested during the period	1,000,000		4,000,000	1,000,000
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
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)	82,750		'	'
Granted (in shares)	49,540		'	'
Nonvested, end of period (in shares)	129,630		82,750	'
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)	$30.62		'	'
Weighted-average grant date fair value per share, granted (in dollars per share)	$33.84		$31.30	$29.20
Weighted-average grant date fair value per share, forfeited (in dollars per share)	($29.17)		'	'
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share)	$31.88		$30.62	'
Period over which performance units fair value is recognized (in years)	'3		'3	'3
Maximum payout percentage of target award	200.00%		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Award vesting period (in years)	'3		'3	'3
Risk-free interest rate	0.36%		0.30%	1.00%
Expected option life (in years)	3		3	3
Expected stock volatility	15.50%		19.30%	23.40%
Stock option activity [Roll Forward]	'		'	'
Forfeited (in shares)	2,660		'	'
LG And E And KU Energy LLC [Member] | All Plans [Member] | Stock Options [Member]	'		'	'
Fair value assumptions and methodology [Abstract]	'		'	'
Risk-free interest rate	1.15%		1.13%	2.34%
Expected option life (in years)	6.48		6.17	5.71
Expected stock volatility	18.50%		20.60%	21.60%
Dividend yield	5.00%		5.00%	5.93%
Stock option activity [Roll Forward]	'		'	'
Outstanding at beginning of period (in shares)	634,847		'	'
Granted (in shares)	501,950		'	'
Exercised (in shares)	-139,641		'	'
Outstanding at end of period (in shares)	997,156		634,847	'
Stock options - additional disclosures [Abstract]	'		'	'
Period that performance goals are evaluated (in years)	'3		'	'
Period after which employee stock options become exercisable in installments (in years)	'1		'	'
Period after which, employee stock options expire (in years)	'10		'	'
Weighted-average exercise price per share at beginning of period (in dollars per share)	$27.11		'	'
Weighted average exercise price per share, granted (in dollars per share)	$29.51		'	'
Weighted average exercise price per share, exercised (in dollars per share)	$26.87		'	'
Weighted average exercise price per share at end of period (in dollars per share)	$28.35		$27.11	'
Weighted average remaining contractual term (in years)	8.4		'	'
Aggregate total intrinsic value	2,000,000		'	'
Options exercisable at end of period (in shares)	250,682		'	'
Weighted average exercise price, options exercisable at end of period (in dollars per share)	$27.22		'	'
Weighted average remaining contractual term, options exercisable at end of period (in years)	7.7		'	'
Aggregate total intrinsic value, options exercisable at end of period	1,000,000		'	'
Weighted average grant date fair value of options granted (in dollars per share)	$2.18		$2.51	$2.47
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	5,000,000
Income tax benefit	3,000,000		4,000,000	2,000,000
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)	15,769,431	[1]	'	'
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%	[1]	'	'
Annual grant limit options (in shares)	3,000,000	[1]	'	'
Annual grant limit for individual participants - performance based awards (in shares)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
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		'	'
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		'	'
Period after which, employee stock options expire upon retirement (in years)	5		'	'
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	'		'	'
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)	'		'	'
Annual grant limit for individual participants - performance based awards	'		'	'
[1]	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_Postemployment_2

Retirement and Postemployment Benefits (Net Period Defined Benefit Costs (Credits) and Other Changes in Plan Assets and Benefit Obligations) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Pension Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	$126		$103		$95
Interest cost	213		220		217
Expected return on plan assets	-293		-259		-245
Amortization of:	'		'		'
Transition (asset) obligation	'		'		'
Prior service cost (credits)	22		24		24
Actuarial (gain) loss	80		42		30
Net periodic defined benefit costs (credits) prior to settlement charges and termination benefits	148		130		121
Settlement charges	'		11		'
Termination benefits	'		'		'
Net periodic defined benefit costs (credits)	148		141		121
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Settlements	'		-11		'
Net (gain) loss	-319		372		117
Prior service costs (credit)	'		'		8
Amortization of: [Abstract]	'		'		'
Transition asset (obligation)	'		'		'
Prior service cost (credit)	-22		-24		-24
Actuarial gain (loss)	-80		-42		-30
Total recognized in OCI and regulatory assets/liabilities	-421		295		71
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-273		436		192
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]	'		'		'
OCI	-228		181		47
Regulatory assets/liabilities	-193		114		24
Total recognized in OCI and regulatory assets/liabilities	-421		295		71
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)	20		'		'
Actuarial (gain) loss	30		'		'
Total	50		'		'
Amortization from Balance Sheet: [Abstract]	'		'		'
AOCI	22		'		'
Regulatory assets/liabilities	28		'		'
Total	50		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	117		119		98
Pension Benefits United Kingdom [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	69		54		44
Interest cost	320		340		282
Expected return on plan assets	-465		-458		-338
Amortization of:	'		'		'
Transition (asset) obligation	'		'		'
Prior service cost (credits)	1		4		4
Actuarial (gain) loss	150		79		57
Net periodic defined benefit costs (credits) prior to settlement charges and termination benefits	75		19		49
Settlement charges	'		'		'
Termination benefits	3	[1]	2	[1]	50	[1]
Net periodic defined benefit costs (credits)	78		21		99
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Settlements	'		'		'
Net (gain) loss	76		1,073		152
Prior service costs (credit)	'		'		'
Amortization of: [Abstract]	'		'		'
Transition asset (obligation)	'		'		'
Prior service cost (credit)	-1		-4		-4
Actuarial gain (loss)	-150		-79		-57
Total recognized in OCI and regulatory assets/liabilities	-75	[2]	990	[2]	91	[2]
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	3	[2]	1,011	[2]	190	[2]
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	-75	[2]	990	[2]	91	[2]
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)	'		'		'
Actuarial (gain) loss	131		'		'
Total	131		'		'
Amortization from Balance Sheet: [Abstract]	'		'		'
AOCI	131		'		'
Regulatory assets/liabilities	'		'		'
Total	131		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	33		25		82
Other Postretirement Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	14		12		12
Interest cost	29		31		33
Expected return on plan assets	-25		-23		-23
Amortization of:	'		'		'
Transition (asset) obligation	'		2		2
Prior service cost (credits)	'		1		'
Actuarial (gain) loss	6		4		6
Net periodic defined benefit costs (credits) prior to settlement charges and termination benefits	24		27		30
Settlement charges	'		'		'
Termination benefits	'		'		'
Net periodic defined benefit costs (credits)	24		27		30
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Settlements	'		'		'
Net (gain) loss	-68		13		-9
Prior service costs (credit)	-3		-1		10
Amortization of: [Abstract]	'		'		'
Transition asset (obligation)	'		-2		-2
Prior service cost (credit)	'		-1		'
Actuarial gain (loss)	-6		-4		-6
Total recognized in OCI and regulatory assets/liabilities	-77		5		-7
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-53		32		23
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]	'		'		'
OCI	-41		12		-6
Regulatory assets/liabilities	-36		-7		-1
Total recognized in OCI and regulatory assets/liabilities	-77		5		-7
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	19		22		24
PPL Energy Supply LLC [Member] | Pension Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	7		6		5
Interest cost	8		7		7
Expected return on plan assets	-10		-9		-9
Amortization of:	'		'		'
Actuarial (gain) loss	3		2		2
Net periodic defined benefit costs (credits)	8		6		5
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Net (gain) loss	-15		16		7
Prior service costs (credit)	'		'		'
Amortization of: [Abstract]	'		'		'
Actuarial gain (loss)	-3		-2		-2
Total recognized in OCI and regulatory assets/liabilities	-18		14		5
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-10		20		10
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]	'		'		'
Total recognized in OCI and regulatory assets/liabilities	-18		14		5
Estimated Amounts to be Amortized From AOCI and Regulatory Assets into Net Periodic Benefit Costs in the Next Fiscal Period (Details) [Abstract]	'		'		'
Actuarial (gain) loss	2		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	45		37		27
PPL Energy Supply LLC [Member] | Pension Benefits United States [Member] | PPL Services [Member]	'		'		'
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]	'		'		'
Costs allocated to subsidiary by plan sponsors	38		31		23
PPL Energy Supply LLC [Member] | Other Postretirement Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	1		1		1
Interest cost	'		1		1
Expected return on plan assets	'		'		'
Amortization of:	'		'		'
Actuarial (gain) loss	'		'		'
Net periodic defined benefit costs (credits)	1		2		2
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Net (gain) loss	-1		'		-2
Prior service costs (credit)	-3		-1		'
Amortization of: [Abstract]	'		'		'
Actuarial gain (loss)	'		'		'
Total recognized in OCI and regulatory assets/liabilities	-4		-1		-2
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-3		1		'
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		-1		-2
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	6		6		7
PPL Energy Supply LLC [Member] | Other Postretirement Benefits United States [Member] | PPL Services [Member]	'		'		'
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]	'		'		'
Costs allocated to subsidiary by plan sponsors	5		5		6
PPL Electric Utilities Corp [Member] | Pension Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	18	[3]	19	[3]	14	[3]
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	3	[3]	3	[3]	4	[3]
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	26		22		24
Interest cost	62		64		67
Expected return on plan assets	-82		-70		-64
Amortization of:	'		'		'
Transition (asset) obligation	'		'		'
Prior service cost (credits)	5		5		5
Actuarial (gain) loss	33		22		24
Net periodic defined benefit costs (credits)	44		43		56
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Net (gain) loss	-116		96		29
Prior service costs (credit)	'		'		8
Amortization of: [Abstract]	'		'		'
Transition asset (obligation)	'		'		'
Prior service cost (credit)	-5		-5		-5
Actuarial gain (loss)	-33		-22		-24
Total recognized in OCI and regulatory assets/liabilities	-154		69		8
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-110		112		64
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]	'		'		'
OCI	-46		34		1
Regulatory assets/liabilities	-108		35		7
Total recognized in OCI and regulatory assets/liabilities	-154		69		8
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	13		'		'
Total	18		'		'
Amortization from Balance Sheet: [Abstract]	'		'		'
Total	18		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	32		31		40
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		4
Interest cost	8		9		10
Expected return on plan assets	-5		-4		-3
Amortization of:	'		'		'
Transition (asset) obligation	'		2		2
Prior service cost (credits)	3		3		2
Actuarial (gain) loss	'		-1		'
Net periodic defined benefit costs (credits)	11		13		15
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Net (gain) loss	-14		-11		-3
Prior service costs (credit)	'		'		11
Amortization of: [Abstract]	'		'		'
Transition asset (obligation)	'		-2		-2
Prior service cost (credit)	-3		-3		-2
Actuarial gain (loss)	'		1		'
Total recognized in OCI and regulatory assets/liabilities	-17		-15		4
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-6		-2		19
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]	'		'		'
OCI	-1		-1		2
Regulatory assets/liabilities	-16		-14		2
Total recognized in OCI and regulatory assets/liabilities	-17		-15		4
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	'		-1		'
Total	'		1		'
Amortization from Balance Sheet: [Abstract]	'		'		'
Total	'		1		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	8		9		11
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits): [ Abstract]	'		'		'
Service cost	2		2		2
Interest cost	14		14		14
Expected return on plan assets	-20		-19		-18
Amortization of:	'		'		'
Prior service cost (credits)	2		3		2
Actuarial (gain) loss	14		11		11
Net periodic defined benefit costs (credits)	12		11		11
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]	'		'		'
Net (gain) loss	-20		18		15
Prior service costs (credit)	'		'		9
Amortization of: [Abstract]	'		'		'
Prior service cost (credit)	-2		-2		-2
Actuarial gain (loss)	-14		-11		-11
Total recognized in OCI and regulatory assets/liabilities	-36		5		11
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	-24		16		22
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	-36		5		11
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	6		'		'
Total	8		'		'
Amortization from Balance Sheet: [Abstract]	'		'		'
Total	8		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	14		13		16
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		5		7
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	4		5		5
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		5		5
Kentucky Utilities Co [Member] | Pension Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	9	[3]	8	[3]	10	[3]
Kentucky Utilities Co [Member] | Other Postretirement Benefits United States [Member]	'		'		'
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]	'		'		'
Net periodic defined benefit costs (credits) charged to operating expense, excluding amounts charged to construction and other non-expense accounts	$2	[3]	$3	[3]	$4	[3]
[1]	Related to the WPD Midlands separations in the U.K.
[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.

Retirement_and_Postemployment_3

Retirement and Postemployment Benefits (Weighted-Average Assumptions, Cost Trend Rates and Funded Status) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Contributions to specific plan	$68		$59		$67
Significant Specific Multiemployer Plan [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Employer Identification Number	'232004424		'		'
Plan number of pension plan	'001		'		'
Contributions to specific plan	5		'		'
Threshold, as a percentage, of contributions by individual contributors to a specific plan that if exceeded require disclosure	5.00%		'		'
Number of subsidiaries whose contributions, on a combined basis, exceeded 5% of a specific plan's contributions	3		'		'
Threshold, as a percentage, of contributions to a specific plan that if exceeded require disclosure	5.00%		'		'
Expiration date of the collective-bargaining agreement	30-Apr-14		'		'
Multiemployer Plan, period contributions	'		5		5
Multiemployer Pension Plans [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Multiemployer Plan, number of plans	70		'		'
Pension Benefits United States [Member]	'		'		'
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]	'		'		'
Benefit obligations valuation discount rate	5.12%		4.22%		'
Benefit obligations valuation rate of compensation increase	3.97%		3.98%		'
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]	'		'		'
Net periodic benefit costs discount rate	4.22%		5.06%		5.42%
Net periodic benefit costs rate of compensation increase	3.98%		4.02%		4.88%
Net periodic benefit costs expected return on plan assets	7.03%	[1]	7.07%	[1]	7.25%	[1]
Assumed Health Care Cost Trend Rates (Details) [Abstract]	'		'		'
Health care cost trend rate assumed for next year, obligations	7.60%		8.00%		8.50%
Health care cost trend rate assumed for next year, cost	8.00%		8.50%		9.00%
Rate to which the cost trend rate is assumed to decline, obligations	5.00%		5.50%		5.50%
Rate to which the cost trend rate is assumed to decline,cost	5.50%		5.50%		5.50%
Year that the rate reaches the ultimate trend rate, obligations	'2020		'2019		'2019
Year that the rate reaches the ultimate trend rate, cost	'2019		'2019		'2019
Change in Benefit Obligation [Roll Forward]	'		'		'
Benefit Obligation, beginning of period	5,046		4,381		'
Service cost	126		103		95
Interest cost	213		220		217
Participant contributions	'		'		'
Plan amendments	'		'		'
Actuarial (gain) loss	-540		546		'
Settlements	'		-25		'
Termination benefits	'		'		'
Net transfer in (out)	'		'		'
Actual expenses paid	'		-3		'
Gross benefits paid	-254	[2]	-176		'
Federal subsidy	'		'		'
Currency conversion	'		'		'
Benefit Obligation, end of period	4,591		5,046		4,381
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	3,939		3,471		'
Actual return on plan assets	72		432		'
Employer contributions	399		239		'
Participant contributions	'		'		'
Settlements	'		-25		'
Actual expenses paid	'		-2		'
Gross benefits paid	-254	[2]	-176		'
Currency conversion	'		'		'
Balance at end of period	4,156		3,939		3,471
Lump sum cash payouts made to terminated vested employees	64		'		'
Funded Status, end of period	-435		-1,107		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	-8		-8		'
Noncurrent liability	-427		-1,099		'
Net amount recognized, end of period	-435		-1,107		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	69		91		'
Net actuarial loss	842		1,241		'
Total	911		1,332		'
Total accumulated benefit obligation for defined benefit pension plans	4,191		4,569		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
AOCI	430		659		'
Regulatory assets/liabilities	481		673		'
Total	911		1,332		'
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Value of Plan Assets (Details) [Abstract]	'		'		'
Projected benefit obligations	4,591		5,046		'
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	4,156		3,939		'
Accumulated benefit obligation	572		4,569		'
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	431		3,939		'
Pension Benefits United States [Member] | Multiemployer Pension Plans [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Contributions to specific plan	36		31		36
Pension Benefits United Kingdom [Member]	'		'		'
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]	'		'		'
Benefit obligations valuation discount rate	4.41%		4.27%		'
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	4.27%		5.24%		5.59%
Net periodic benefit costs rate of compensation increase	4.00%		4.00%		3.75%
Net periodic benefit costs expected return on plan assets	7.16%	[1]	7.17%	[1]	7.04%	[1]
Change in Benefit Obligation [Roll Forward]	'		'		'
Benefit Obligation, beginning of period	7,888		6,638		'
Service cost	69		54		44
Interest cost	320		340		282
Participant contributions	15		15		'
Plan amendments	'		'		'
Actuarial (gain) loss	46		1,081		'
Settlements	'		'		'
Termination benefits	3		2		'
Net transfer in (out)	'		12		'
Actual expenses paid	'		'		'
Gross benefits paid	-375		-397		'
Federal subsidy	'		'		'
Currency conversion	177		143		'
Benefit Obligation, end of period	8,143		7,888		6,638
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	6,911		6,351		'
Actual return on plan assets	438		476		'
Employer contributions	134		341		'
Participant contributions	15		15		'
Settlements	'		'		'
Actual expenses paid	'		'		'
Gross benefits paid	-375		-397		'
Currency conversion	161		125		'
Balance at end of period	7,284		6,911		6,351
Funded Status, end of period	-859		-977		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	'		'		'
Noncurrent liability	-859		-977		'
Net amount recognized, end of period	-859		-977		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	'		1		'
Net actuarial loss	2,112		2,184		'
Total	2,112	[3]	2,185	[3]	'
Total accumulated benefit obligation for defined benefit pension plans	7,542		7,259		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
Total	2,112	[3]	2,185	[3]	'
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Value of Plan Assets (Details) [Abstract]	'		'		'
Projected benefit obligations	8,143		7,888		'
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	7,284		6,911		'
Accumulated benefit obligation	3,441		3,349		'
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	3,131		2,812		'
Other Postretirement Benefits United States [Member]	'		'		'
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]	'		'		'
Benefit obligations valuation discount rate	4.91%		4.00%		'
Benefit obligations valuation rate of compensation increase	3.96%		3.97%		'
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]	'		'		'
Net periodic benefit costs discount rate	4.00%		4.80%		5.14%
Net periodic benefit costs rate of compensation increase	3.97%		4.00%		4.90%
Net periodic benefit costs expected return on plan assets	5.94%	[1]	5.99%	[1]	6.57%	[1]
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	722		687		'
Service cost	14		12		12
Interest cost	29		31		33
Participant contributions	12		'		'
Plan amendments	-4		-1		'
Actuarial (gain) loss	-54		31		'
Settlements	'		'		'
Termination benefits	'		'		'
Net transfer in (out)	'		'		'
Actual expenses paid	'		'		'
Gross benefits paid	-57		-46		'
Federal subsidy	'		2		'
Currency conversion	'		'		'
Benefit Obligation, end of period	662		722		687
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	421		391		'
Actual return on plan assets	37		42		'
Employer contributions	30		27		'
Participant contributions	12		'		'
Settlements	'		'		'
Actual expenses paid	'		'		'
Gross benefits paid	-54		-44		'
Currency conversion	'		'		'
Balance at end of period	446		421		391
Funded Status, end of period	-216		-301		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	-1		-1		'
Noncurrent liability	-215		-300		'
Net amount recognized, end of period	-216		-301		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	-11		-7		'
Net actuarial loss	33		106		'
Total	22		99		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
AOCI	19		59		'
Regulatory assets/liabilities	3		40		'
Total	22		99		'
Other Postretirement Benefits United States [Member] | Multiemployer Other Postretirement Medical Plans [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Contributions to specific plan	32		28		31
PPL Energy Supply LLC [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Multiemployer Plan, period contributions	68		59		67
PPL Energy Supply LLC [Member] | Significant Specific Multiemployer Plan [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Employer Identification Number	'232004424		'		'
Plan number of pension plan	'001		'		'
Contributions to specific plan	5		'		'
Threshold, as a percentage, of contributions by individual contributors to a specific plan that if exceeded require disclosure	5.00%		'		'
Number of subsidiaries whose contributions, on a combined basis, exceeded 5% of a specific plan's contributions	3		'		'
Threshold, as a percentage, of contributions to a specific plan that if exceeded require disclosure	5.00%		'		'
Expiration date of the collective-bargaining agreement	30-Apr-14		'		'
Multiemployer Plan, period contributions	'		5		5
PPL Energy Supply LLC [Member] | Multiemployer Pension Plans [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Multiemployer Plan, number of plans	70		'		'
PPL Energy Supply 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	5.18%		4.25%		'
Benefit obligations valuation rate of compensation increase	3.94%		3.95%		'
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]	'		'		'
Net periodic benefit costs discount rate	4.25%		5.12%		5.47%
Net periodic benefit costs rate of compensation increase	3.95%		4.00%		4.75%
Net periodic benefit costs expected return on plan assets	7.00%	[1]	7.00%	[1]	7.25%	[1]
Assumed Health Care Cost Trend Rates (Details) [Abstract]	'		'		'
Health care cost trend rate assumed for next year, obligations	7.60%		8.00%		8.50%
Health care cost trend rate assumed for next year, cost	8.00%		8.50%		9.00%
Rate to which the cost trend rate is assumed to decline, obligations	5.00%		5.50%		5.50%
Rate to which the cost trend rate is assumed to decline,cost	5.50%		5.50%		5.50%
Year that the rate reaches the ultimate trend rate, obligations	'2020		'2019		'2019
Year that the rate reaches the ultimate trend rate, cost	'2019		'2019		'2019
Change in Benefit Obligation [Roll Forward]	'		'		'
Benefit Obligation, beginning of period	176		143		'
Service cost	7		6		5
Interest cost	8		7		7
Plan amendments	'		'		'
Actuarial (gain) loss	-23		23		'
Gross benefits paid	-5		-3		'
Benefit Obligation, end of period	163		176		143
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	149		132		'
Actual return on plan assets	3		16		'
Employer contributions	'		4		'
Gross benefits paid	-5		-3		'
Balance at end of period	147		149		132
Funded Status, end of period	-16		-27		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	'		'		'
Noncurrent liability	-16		-27		'
Net amount recognized, end of period	-16		-27		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	'		'		'
Net actuarial loss	34		52		'
Total	34		52		'
Total accumulated benefit obligation for defined benefit pension plans	163		176		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
Total	34		52		'
PPL Energy Supply LLC [Member] | Pension Benefits United States [Member] | PPL Services Funded Status Allocation [Member]	'		'		'
Change in Plan Assets [Roll Forward]	'		'		'
Funded Status, end of period	96		268		'
PPL Energy Supply LLC [Member] | Pension Benefits United States [Member] | Multiemployer Pension Plans [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Multiemployer Plan, period contributions	36		31		36
PPL Energy Supply 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	4.51%		3.77%		'
Benefit obligations valuation rate of compensation increase	3.94%		3.95%		'
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]	'		'		'
Net periodic benefit costs discount rate	3.77%		4.60%		4.95%
Net periodic benefit costs rate of compensation increase	3.95%		4.00%		4.75%
Change in Benefit Obligation [Roll Forward]	'		'		'
Benefit Obligation, beginning of period	17		17		'
Service cost	1		1		1
Interest cost	'		1		1
Plan amendments	-4		-1		'
Actuarial (gain) loss	-1		'		'
Gross benefits paid	-1		-1		'
Benefit Obligation, end of period	12		17		17
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	'		'		'
Actual return on plan assets	'		'		'
Employer contributions	1		'		'
Gross benefits paid	-1		'		'
Balance at end of period	'		'		'
Funded Status, end of period	-12		-17		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	-1		-1		'
Noncurrent liability	-11		-16		'
Net amount recognized, end of period	-12		-17		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	-5		-1		'
Net actuarial loss	1		2		'
Total	-4		1		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
Total	-4		1		'
PPL Energy Supply LLC [Member] | Other Postretirement Benefits United States [Member] | PPL Services Funded Status Allocation [Member]	'		'		'
Change in Plan Assets [Roll Forward]	'		'		'
Funded Status, end of period	35		60		'
PPL Energy Supply LLC [Member] | Other Postretirement Benefits United States [Member] | Multiemployer Other Postretirement Medical Plans [Member]	'		'		'
Multiemployer Plans (Numeric) [Abstract]	'		'		'
Multiemployer Plan, period contributions	32		28		31
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	96		237		'
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	41		61		'
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	5.18%		4.24%		'
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	4.24%		5.09%		5.49%
Net periodic benefit costs rate of compensation increase	4.00%		4.00%		5.25%
Net periodic benefit costs expected return on plan assets	7.10%	[1]	7.25%	[1]	7.25%	[1]
Assumed Health Care Cost Trend Rates (Details) [Abstract]	'		'		'
Health care cost trend rate assumed for next year, obligations	7.60%		8.00%		8.50%
Health care cost trend rate assumed for next year, cost	8.00%		8.50%		9.00%
Rate to which the cost trend rate is assumed to decline, obligations	5.00%		5.50%		5.50%
Rate to which the cost trend rate is assumed to decline,cost	5.50%		5.50%		5.50%
Year that the rate reaches the ultimate trend rate, obligations	'2020		'2019		'2019
Year that the rate reaches the ultimate trend rate, cost	'2019		'2019		'2019
Change in Benefit Obligation [Roll Forward]	'		'		'
Benefit Obligation, beginning of period	1,487		1,306		'
Service cost	26		22		24
Interest cost	62		64		67
Participant contributions	'		'		'
Actuarial (gain) loss	-177		144		'
Gross benefits paid	-70	[4]	-48		'
Federal subsidy	'		'		'
Benefit Obligation, end of period	1,328		1,487		1,306
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	1,070		944		'
Actual return on plan assets	21		117		'
Employer contributions	152		57		'
Participant contributions	'		'		'
Gross benefits paid	-70	[4]	-48		'
Balance at end of period	1,173		1,070		944
Lump sum cash payouts made to terminated vested employees	21		'		'
Funded Status, end of period	-155		-417		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	-3		-3		'
Noncurrent liability	-152		-414		'
Net amount recognized, end of period	-155		-417		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	24		28		'
Net actuarial loss	205		355		'
Total	229		383		'
Total accumulated benefit obligation for defined benefit pension plans	1,176		1,319		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
AOCI	-19		27		'
Regulatory assets/liabilities	248		356		'
Total	229		383		'
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Value of Plan Assets (Details) [Abstract]	'		'		'
Projected benefit obligations	1,328		1,487		'
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	1,173		1,070		'
Accumulated benefit obligation	350		1,319		'
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	284		1,070		'
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	4.91%		3.99%		'
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	3.99%		4.78%		5.12%
Net periodic benefit costs rate of compensation increase	4.00%		4.00%		5.25%
Net periodic benefit costs expected return on plan assets	6.76%	[1]	7.02%	[1]	7.16%	[1]
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	209		214		'
Service cost	5		4		4
Interest cost	8		9		10
Participant contributions	7		8		'
Actuarial (gain) loss	-18		-8		'
Gross benefits paid	-18		-19		'
Federal subsidy	'		1		'
Benefit Obligation, end of period	193		209		214
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	68		58		'
Actual return on plan assets	1		8		'
Employer contributions	16		13		'
Participant contributions	7		8		'
Gross benefits paid	-18		-19		'
Balance at end of period	74		68		58
Funded Status, end of period	-119		-141		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Current liability	'		'		'
Noncurrent liability	-119		-141		'
Net amount recognized, end of period	-119		-141		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	8		11		'
Net actuarial loss	-30		-17		'
Total	-22		-6		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
AOCI	'		'		'
Regulatory assets/liabilities	-22		-6		'
Total	-22		-6		'
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	5.13%		4.20%		'
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]	'		'		'
Net periodic benefit costs discount rate	4.20%		5.00%		5.39%
Net periodic benefit costs expected return on plan assets	7.10%	[1]	7.25%	[1]	7.25%	[1]
Change in Benefit Obligation [Roll Forward]	'		'		'
Benefit Obligation, beginning of period	331		298		'
Service cost	2		2		2
Interest cost	14		14		14
Actuarial (gain) loss	-35		32		'
Gross benefits paid	-21	[5]	-14		'
Benefit Obligation, end of period	291		331		298
Change in Plan Assets [Roll Forward]	'		'		'
Balance at beginning of period	287		256		'
Actual return on plan assets	4		32		'
Employer contributions	11		13		'
Gross benefits paid	-21	[5]	-14		'
Balance at end of period	281		287		256
Lump sum cash payouts made to terminated vested employees	7		'		'
Funded Status, end of period	-10		-44		'
Amounts recognized in the Balance Sheets consist of: [Abstract]	'		'		'
Noncurrent liability	-10		-44		'
Net amount recognized, end of period	-10		-44		'
Amounts recognized in AOCI and regulatory asets/liabilities (pre-tax): [Abstract]	'		'		'
Prior service cost (credit)	15		17		'
Net actuarial loss	90		123		'
Total	105		140		'
Total accumulated benefit obligation for defined benefit pension plans	288		328		'
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]	'		'		'
Total	105		140		'
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	9		58		'
Louisville Gas And Electric Co [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	'		'		'
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]	'		'		'
Net periodic benefit costs discount rate	'		'		'
Net periodic benefit costs expected return on plan assets	'		'		'
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	73		81		'
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	11		104		'
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		$53		'
[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]	Certain U.S. pension plans offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump sum payment. The increase in gross benefits paid is primarily the result of $64 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with these offerings.
[3]	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.
[4]	Certain LKE pension plans offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The increase in gross benefits paid is primarily the result of $21 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with these offerings.
[5]	LG&E's pension plan offered a limited-time program in 2013 during which terminated vested participants could elect to receive their accrued pension benefit as a one-time lump-sum payment. The increase in gross benefits paid is primarily the result of $7 million of lump-sum cash payments made to terminated vested participants in 2013 in connection with this offering.

Retirement_and_Postemployment_4

Retirement and Postemployment Benefits (Plan Assets and Expected Cash Flows) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

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Dec. 31, 2013

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Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

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Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

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Dec. 31, 2012

Dec. 31, 2013

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Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

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Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

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Master Trust [Member]

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Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

Master Trust [Member]

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Information About Plan Assets (Numeric) [Abstract]

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'

'

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'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of plan U.S. pension trust assets that relate to PPL subsidiary

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$147

$149

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,200

$1,100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$281

$287

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Undivided interest percentage in each asset category that PPL subsidiary holds

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

4.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

29.00%

26.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.00%

7.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assumptions Used in Calculations (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

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'

'

'

'

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'

The limited lives of four partnership of private equity investments (in years)

'

'

'

10

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10

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10

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'

The limited lives of fifth partnership of private equity investments (in years)

'

'

'

15

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15

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'

15

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15

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'

The amount of potential liability that maybe required to be funded by the master trust during life of the partnership

'

'

'

76

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'

'

'

'

'

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'

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76

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76

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76

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'

'

Number of months from date of purchase that investment must mature

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

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'

13

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'

'

'

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'

'

'

13

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum number of days notice required to redeem shares for investments in hedge funds

'

'

'

65

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

65

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

65

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum number of days notice required to redeem shares for investments in hedge funds

'

'

'

95

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

95

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

95

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'

'

'

'

'

95

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Actual Allocation by Plan Asset (Details) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of trust assets

'

'

'

100.00%

[1]

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

59.00%

[1]

58.00%

30.00%

[1]

31.00%

17.00%

[1],[2]

18.00%

[2]

12.00%

[1]

9.00%

39.00%

[1]

41.00%

40.00%

[1],[2]

40.00%

[2]

-1.00%

[1]

1.00%

2.00%

[1]

1.00%

100.00%

100.00%

'

'

'

'

'

'

'

0.00%

0.00%

'

'

'

'

'

'

7.00%

6.00%

'

'

'

'

'

'

5.00%

14.00%

'

'

'

'

'

'

3.00%

0.00%

'

'

'

'

'

'

5.00%

0.00%

'

'

'

'

'

'

8.00%

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.00%

2.00%

'

'

'

'

'

'

19.00%

18.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

[3]

51.00%

[3]

6.00%

6.00%

'

'

'

'

'

'

'

'

100.00%

100.00%

'

4.00%

[4]

3.00%

[4]

'

'

'

'

'

'

'

55.00%

46.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

41.00%

[5]

51.00%

[5]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

59.00%

[1]

58.00%

30.00%

[1]

31.00%

17.00%

[1],[2]

18.00%

[2]

12.00%

[1]

9.00%

39.00%

[1]

41.00%

40.00%

[1],[2]

40.00%

[2]

-1.00%

[1]

1.00%

2.00%

[1]

1.00%

'

'

'

'

'

100.00%

[1]

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

59.00%

[1]

58.00%

30.00%

[1]

31.00%

17.00%

[1],[2]

18.00%

[2]

12.00%

[1]

9.00%

39.00%

[1]

41.00%

40.00%

[1],[2]

40.00%

[2]

-1.00%

[1]

1.00%

2.00%

[1]

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

59.00%

[1]

58.00%

30.00%

[1]

31.00%

17.00%

[1],[2]

18.00%

[2]

12.00%

[1]

9.00%

39.00%

[1]

41.00%

40.00%

[1],[2]

40.00%

[2]

-1.00%

[1]

1.00%

2.00%

[1]

1.00%

Target Allocations (Details ) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

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'

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'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

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'

'

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'

'

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'

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'

'

'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Target asset allocation

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.00%

'

'

'

'

'

'

'

4.00%

'

'

'

'

'

'

'

3.00%

'

'

'

'

'

'

'

5.00%

'

'

'

'

'

'

'

8.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

'

'

'

'

'

'

19.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

45.00%

[3]

'

6.00%

'

'

'

'

'

'

'

'

'

100.00%

'

'

5.00%

[4]

'

'

'

'

'

'

'

'

45.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

[5]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

Target asset allocation - PPL Plans

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Target asset allocation - LKE Plans

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

[1]

'

'

'

'

'

'

'

43.00%

[1]

'

'

'

'

'

2.00%

[1]

'

Defined benefit plan fair value of plan assets (Details) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value at end of period

'

4,156

3,471

4,271

'

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,284

'

6,351

1,112

957

6,172

5,954

'

'

10

'

10

14

'

'

'

'

523

'

267

223

256

217

'

'

355

'

275

720

80

236

'

'

226

'

180

'

46

'

'

'

352

'

254

'

98

'

'

'

411

'

126

'

285

231

'

'

161

'

'

'

161

'

'

'

485

'

'

'

485

127

'

'

1,384

'

'

'

1,384

1,220

'

'

504

593

'

'

504

593

'

'

2,426

2,907

'

'

2,426

2,907

'

'

'

'

'

'

447

423

'

'

447

423

'

'

446

'

391

'

'

12

12

13

'

'

'

'

'

'

182

145

'

'

182

145

'

'

100

119

'

'

100

119

'

'

'

'

36

41

'

'

36

41

'

'

1

[6]

1

[6]

115

[7]

102

[7]

330

318

12

13

318

305

'

'

147

132

4,271

4,052

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,173

944

4,271

4,052

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

74

58

12

12

13

'

'

'

'

182

145

'

'

182

145

'

'

100

119

'

'

100

119

'

'

36

41

'

'

36

41

'

'

1

[6]

1

[6]

115

[7]

102

[7]

330

318

12

13

318

305

'

'

281

287

256

4,271

4,052

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Change in Fair Value of Level 3 Plan Assets [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

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'

'

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'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period

'

3,939

3,471

4,052

'

1,130

1,288

3,000

2,618

146

98

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

'

963

874

'

'

940

847

27

7

24

24

'

'

24

23

1

'

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

75

45

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

42

46

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,911

'

6,351

1,112

957

6,172

5,954

'

'

14

'

10

14

'

'

'

'

440

'

267

223

256

217

'

'

956

'

275

720

80

236

'

'

'

'

180

'

46

'

'

'

'

'

254

'

98

'

'

'

231

'

126

'

285

231

'

'

161

'

'

'

161

'

'

'

127

'

'

'

485

127

'

'

1,220

'

'

'

1,384

1,220

'

'

504

593

'

'

504

593

'

'

2,426

2,907

'

'

2,426

2,907

'

'

'

'

'

'

447

423

'

'

447

423

'

'

421

'

391

'

'

13

12

13

'

'

'

'

'

'

182

145

'

'

182

145

'

'

100

119

'

'

100

119

'

'

'

'

36

41

'

'

36

41

'

'

1

[6]

1

[6]

115

[7]

102

[7]

330

318

12

13

318

305

'

'

149

132

4,052

'

1,130

1,288

3,000

2,618

146

98

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

'

963

874

'

'

940

847

27

7

24

24

'

'

24

23

1

'

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

75

45

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

42

46

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,070

944

4,052

'

1,130

1,288

3,000

2,618

146

98

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

'

963

874

'

'

940

847

27

7

24

24

'

'

24

23

1

'

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

75

45

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

42

46

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

68

58

13

12

13

'

'

'

'

182

145

'

'

182

145

'

'

100

119

'

'

100

119

'

'

36

41

'

'

36

41

'

'

1

[6]

1

[6]

115

[7]

102

[7]

330

318

12

13

318

305

'

'

281

287

256

4,052

'

1,130

1,288

3,000

2,618

146

98

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

'

963

874

'

'

940

847

27

7

24

24

'

'

24

23

1

'

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

75

45

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

42

46

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Actual return on plan assets relating to assets still held at the reporting date

'

'

'

'

'

'

'

'

'

5

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Actual return on plan assets relating to assets sold during the period

'

'

'

'

'

'

'

'

'

5

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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5

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5

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5

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Purchases, sales and settlements

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-14

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1

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-9

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2

20

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-7

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-14

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1

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-9

21

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2

20

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-7

-7

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-14

35

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1

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-9

21

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2

20

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-7

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-14

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1

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-9

21

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2

20

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-7

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Transfers from level 2 to level 3

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1

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1

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1

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1

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1

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1

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1

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'

Transfers from level 3 to level 2

'

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'

-1

-4

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-4

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-1

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-1

-4

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-4

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-1

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-1

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-4

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-1

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1

-4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-4

'

'

'

'

'

'

-1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period

'

4,156

3,471

4,271

'

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,284

'

6,351

1,112

957

6,172

5,954

'

'

10

'

10

14

'

'

'

'

523

'

267

223

256

217

'

'

355

'

275

720

80

236

'

'

226

'

180

'

46

'

'

'

352

'

254

'

98

'

'

'

411

'

126

'

285

231

'

'

161

'

'

'

161

'

'

'

485

'

'

'

485

127

'

'

1,384

'

'

'

1,384

1,220

'

'

504

593

'

'

504

593

'

'

2,426

2,907

'

'

2,426

2,907

'

'

'

'

'

'

447

423

'

'

447

423

'

'

446

'

391

'

'

12

12

13

'

'

'

'

'

'

182

145

'

'

182

145

'

'

100

119

'

'

100

119

'

'

'

'

36

41

'

'

36

41

'

'

1

[6]

1

[6]

115

[7]

102

[7]

330

318

12

13

318

305

'

'

147

132

4,271

4,052

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,173

944

4,271

4,052

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

74

58

12

12

13

'

'

'

'

182

145

'

'

182

145

'

'

100

119

'

'

100

119

'

'

36

41

'

'

36

41

'

'

1

[6]

1

[6]

115

[7]

102

[7]

330

318

12

13

318

305

'

'

281

287

256

4,271

4,052

1,130

1,288

3,000

2,618

141

146

120

84

120

84

'

'

'

'

480

558

134

206

346

352

'

'

137

124

137

124

'

'

'

'

749

676

13

56

736

620

'

'

630

557

163

184

467

373

'

'

617

704

563

634

54

70

'

'

12

12

'

'

11

11

1

1

963

874

'

'

940

847

23

27

24

24

'

'

24

23

'

1

7

7

'

'

7

7

'

'

108

59

'

'

108

59

'

'

134

93

'

'

134

93

'

'

80

75

'

'

'

'

80

75

210

125

'

'

210

125

'

'

12

2

'

'

12

2

'

'

-49

36

'

'

-49

36

'

'

37

42

'

'

'

'

37

42

'

-11

[6]

-115

-102

4,156

3,939

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount to be contributed to plan in the next fiscal year

'

96

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

313

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

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'

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'

13

'

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'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

Expected amount of benefit payments in the next period for non-qualified plans

'

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

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'

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'

3

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'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Recurrence of formal actuarial valuations (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

3

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'

'

'

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'

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'

'

'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of deficit funding requirements permitted to recover in rates

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

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'

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'

'

75.00%

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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Estimated Future Benefit Payments (Details) [Abstract]

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2014

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387

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53

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1

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58

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13

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15

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2015

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222

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392

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55

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6

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2

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57

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15

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64

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2018

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8

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2

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69

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'

'

2019-2023

'

1,545

'

'

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'

'

'

'

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'

'

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'

'

'

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'

2,128

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'

338

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'

52

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'

11

'

'

425

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'

81

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'

99

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'

Expected Federal Subsidy (Details) [Abstract]

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'

Federal subsidy 2014

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1

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1

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Federal subsidy 2015

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[1]

Allocations exclude consideration of cash for the WKE Bargaining Employees' Retirement Plan and a guaranteed annuity contract held by the LG&E and KU Retirement Plan.

[2]

Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.

[3]

Includes commingled debt funds.

[4]

Includes money market funds.

[5]

Includes commingled debt funds and debt securities.

[6]

Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.

[7]

LKE's other postretirement benefit plan was invested primarily in a 401(h) account as disclosed in the PPL Services Corporation Master Trust.

Retirement_and_Postemployment_5

Retirement and Postemployment Benefits (Savings Plans and Employee Stock Ownership Plan) (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Stock Ownership Plan [Member]	'	'	'
Employee Stock Ownership Plan (ESOP) Disclosures (Numeric) [Line Item]	'	'	'
Contributions allocated based on this percentage of shares held in existing participants' accounts	75.00%	'	'
Contributions allocated based on this percentage of eligible compensation	25.00%	'	'
Compensation expense for ESOP	'	$8	$8
ESOP shares outstanding at period end	7,699,472	'	'
ESOP shares percentage of total common shares outstanding	1.00%	'	'
Deferred Savings Plans 401K [Member]	'	'	'
Defined Contribution Pension and Other Postretirement Plans [Line Items]	'	'	'
Employer contributions to deferred savings plans	41	36	31
PPL Energy Supply LLC [Member] | Employee Stock Ownership Plan [Member]	'	'	'
Employee Stock Ownership Plan (ESOP) Disclosures (Numeric) [Line Item]	'	'	'
Contributions allocated based on this percentage of shares held in existing participants' accounts	75.00%	'	'
Contributions allocated based on this percentage of eligible compensation	25.00%	'	'
PPL Energy Supply LLC [Member] | Deferred Savings Plans 401K [Member]	'	'	'
Defined Contribution Pension and Other Postretirement Plans [Line Items]	'	'	'
Employer contributions to deferred savings plans	12	12	11
PPL Electric Utilities Corp [Member] | Employee Stock Ownership Plan [Member]	'	'	'
Employee Stock Ownership Plan (ESOP) Disclosures (Numeric) [Line Item]	'	'	'
Contributions allocated based on this percentage of shares held in existing participants' accounts	75.00%	'	'
Contributions allocated based on this percentage of eligible compensation	25.00%	'	'
PPL Electric Utilities Corp [Member] | Deferred Savings Plans 401K [Member]	'	'	'
Defined Contribution Pension and Other Postretirement Plans [Line Items]	'	'	'
Employer contributions to deferred savings plans	6	5	5
LG And E And KU Energy LLC [Member] | Deferred Savings Plans 401K [Member]	'	'	'
Defined Contribution Pension and Other Postretirement Plans [Line Items]	'	'	'
Employer contributions to deferred savings plans	13	12	11
Louisville Gas And Electric Co [Member] | Deferred Savings Plans 401K [Member]	'	'	'
Defined Contribution Pension and Other Postretirement Plans [Line Items]	'	'	'
Employer contributions to deferred savings plans	7	6	5
Kentucky Utilities Co [Member] | Deferred Savings Plans 401K [Member]	'	'	'
Defined Contribution Pension and Other Postretirement Plans [Line Items]	'	'	'
Employer contributions to deferred savings plans	6	$6	$6

Jointly_Owned_Facilities_Detai

Jointly Owned Facilities (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Jointly Owned Facilities [Line Items]	'	'
Percentage of leasehold interest in Colstrip Units 1 and 2	'	50.00%
Percentage of leasehold interest in Colstrip Unit 3	'	30.00%
Percentage of interest by Northwestern in Colstrip Unit 4	30.00%	30.00%
Proportionate share by each party of operating and construction costs regarding Colstrip Unit 3 or 4	15.00%	15.00%
Susquehanna Nuclear Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	90.00%	90.00%
Electric plant	4,686	4,628
Accumulated depreciation	3,545	3,530
Construction work in progress	76	65
Conemaugh Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	16.25%	16.25%
Electric plant	247	238
Accumulated depreciation	131	122
Construction work in progress	63	30
Keystone Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	12.34%	12.34%
Electric plant	207	206
Accumulated depreciation	91	82
Construction work in progress	2	3
Trimble County Units 1 and 2 Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	75.00%	75.00%
Electric plant	1,288	1,279
Accumulated depreciation	144	112
Construction work in progress	54	43
Merrill Creek Reservoir [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	8.37%	8.37%
Other property	22	22
Accumulated depreciation	16	15
PPL Energy Supply LLC [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Percentage of leasehold interest in Colstrip Units 1 and 2	'	50.00%
Percentage of leasehold interest in Colstrip Unit 3	'	30.00%
Percentage of interest by Northwestern in Colstrip Unit 4	30.00%	30.00%
Proportionate share by each party of operating and construction costs regarding Colstrip Unit 3 or 4	15.00%	15.00%
PPL Energy Supply LLC [Member] | Susquehanna Nuclear Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	90.00%	90.00%
Electric plant	4,686	4,628
Accumulated depreciation	3,545	3,530
Construction work in progress	76	65
PPL Energy Supply LLC [Member] | Conemaugh Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	16.25%	16.25%
Electric plant	247	238
Accumulated depreciation	131	122
Construction work in progress	63	30
PPL Energy Supply LLC [Member] | Keystone Generation Plant [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	12.34%	12.34%
Electric plant	207	206
Accumulated depreciation	91	82
Construction work in progress	2	3
PPL Energy Supply LLC [Member] | Merrill Creek Reservoir [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	8.37%	8.37%
Other property	22	22
Accumulated depreciation	16	15
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	308	304
Other property	'	'
Accumulated depreciation	42	33
Construction work in progress	18	10
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	980	975
Other property	'	'
Accumulated depreciation	102	79
Construction work in progress	36	33
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
Other property	'	'
Accumulated depreciation	7	5
Construction work in progress	1	'
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	46	46
Other property	'	'
Accumulated depreciation	5	3
Construction work in progress	1	'
Louisville Gas And Electric Co [Member] | Trimble County Unit 1 [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	75.00%	75.00%
Electric plant	308	304
Other property	'	'
Accumulated depreciation	42	33
Construction work in progress	18	10
Louisville Gas And Electric Co [Member] | Trimble County Unit 2 [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	14.25%	14.25%
Electric plant	200	198
Other property	'	'
Accumulated depreciation	19	14
Construction work in progress	14	13
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
Other property	'	'
Accumulated depreciation	3	2
Construction work in progress	'	'
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	69	68
Other property	'	'
Accumulated depreciation	7	6
Construction work in progress	1	2
Louisville Gas And Electric Co [Member] | Cane Run Unit 7 Combined Cycle Gas Turbine [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	22.00%	22.00%
Electric plant	'	'
Other property	'	'
Accumulated depreciation	'	'
Construction work in progress	91	16
Louisville Gas And Electric Co [Member] | Green River Unit Five Combined Cycle Gas Turbine [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	40.00%	'
Electric plant	'	'
Accumulated depreciation	'	'
Construction work in progress	1	'
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	64	64
Other property	'	'
Accumulated depreciation	11	7
Construction work in progress	2	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	42	42
Other property	'	'
Accumulated depreciation	4	2
Construction work in progress	1	'
Kentucky Utilities Co [Member] | Trimble County Unit 2 [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	60.75%	60.75%
Electric plant	780	777
Other property	'	'
Accumulated depreciation	83	65
Construction work in progress	22	20
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
Other property	'	'
Accumulated depreciation	8	4
Construction work in progress	'	'
Kentucky Utilities Co [Member] | Trimble County Units 7 Through 10 [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	63.00%	63.00%
Electric plant	118	116
Other property	'	'
Accumulated depreciation	12	10
Construction work in progress	2	2
Kentucky Utilities Co [Member] | Cane Run Unit 7 Combined Cycle Gas Turbine [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	78.00%	78.00%
Electric plant	'	'
Other property	'	'
Accumulated depreciation	'	'
Construction work in progress	317	53
Kentucky Utilities Co [Member] | Green River Unit Five Combined Cycle Gas Turbine [Member]	'	'
Jointly Owned Facilities [Line Items]	'	'
Ownership interest	60.00%	'
Electric plant	'	'
Other property	'	'
Accumulated depreciation	'	'
Construction work in progress	2	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Energy Purchases, Energy Sales, Other Commitments and Legal Matters) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	Integer
	Y
	MW
Energy Purchase Commitments (Numeric) [Abstract]	'	'	'
Pre-tax charges incurred from coal contract modifications	'	$29,000,000	'
Frequency of competitive solicitations each plan year	'twice	'	'
Shortest term of layered short-term full requirement products (in months)	3	'	'
Longest term of layered short-term full requirement products (in months)	12	'	'
Recurring term of spot market product (in months)	12	'	'
Number of competitive solicitations completed to date under the Public Utility Commission approved purchase plan	2	'	'
Total number of competitive solicitations under the Public Utility Commission approved purchase plan	4	'	'
Hydroelectric License Commitments (Numeric) [Abstract]	'	'	'
Number of hydroelectric facilities owned by PPL Montana	11	'	'
Number of storage reservoirs owned by PPL Montana	1	'	'
Total term, in years, of the Kerr Dam project license	50	'	'
Term, in years, PPL Montana is required to operate the Kerr Dam project	30	'	'
Number of open Memoranda of Understanding related to the issuance of the renewal license for the Missouri-Madison project	2	'	'
Number of dams related to the Missouri-Madison project for which Memoranda of Understanding exists	9	'	'
Estimate Of Remaining Commitment On Specific Missouri Madison Project	29,000,000	'	'
Number of hydroelectric facilities owned by PPL Montana to be sold	11	'	'
Legal Matters - Montana Hydroelectric Litigation (Numeric) [Abstract]	'	'	'
Contingency reversal during period, impact to Operation and Maintenance	'	'	65,000,000
Contingency reversal during period, impact to interest expense	'	'	10,000,000
Legal Matters - Bankruptcy of Southern Montana Electric Generation and Transmission Cooperative, Inc. (Numeric) [Abstract]	'	'	'
Reserve related to the accounts receivable from a bankrupt counterparty	'	21,000,000	'
Total unsecured claim as a result of the termination of the SMGT contract	'	375,000,000	'
Legal Matters - Sierra Club Litigation (Numeric) [Abstract]	'	'	'
Number of separate claims included in the original complaint against PPL Montana	39	'	'
Number of original claims against Colstrip that did not allege Prevention of Significant Deterioration but alleged Title V operating permit violations	3	'	'
Average requested amount, per day per violation, of injuctive relief and civil penalities	36,000,000	'	'
Amount of civil penalities to be used for beneficial mitigation projects	100,000,000	'	'
Estimated number of post-2000 projects alleged not to be in compliance with the Clean Air Act	40	'	'
Regulatory Issues - Maryland Capacity Order (Numeric) [Abstract]	'	'	'
Number electric utilities ordered to enter into long term contracts	3	'	'
Capacity of natural gas-fired combined-cycle generating facility (in MW)	661	'	'
Regulatory Issues - Pacific Northwest Markets (Numeric) [Abstract]	'	'	'
Settlement amount reached with one of the parties	'	75,000	'
Amount of claim sought by City of Tacoma	'	23,000,000	'
Amount for claims remaining unsettled at period end	50,000,000	'	'
Regulatory Issues - FERC Market-Based Rate Authority (Numeric) [Abstract]	'	'	'
Time from December 1998 that a subsidiary was required to respond to the FERC market analysis information request (in years)	3	'	'
Frequency, after initial filing, that a subsidiary is required to respond to the FERC market analysis information request (in years)	3	'	'
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]	'	'	'
Maximum per day penalties for reliability violations	1,000,000	'	'
Settled Litigation - Spent Nuclear Fuel Litigation (Numeric) [Abstract]	'	'	'
PPL's share of settlement for spent nuclear fuel litigation	'	'	56,000,000
Power Purchase [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
2014	26,000,000	'	'
2015	26,000,000	'	'
2016	26,000,000	'	'
2017	27,000,000	'	'
2018	29,000,000	'	'
Thereafter	728,000,000	'	'
Total future obligation	862,000,000	'	'
Purchases	26,000,000	29,000,000	32,000,000
PPL Energy Supply LLC [Member]	'	'	'
Energy Purchase Commitments (Numeric) [Abstract]	'	'	'
Pre-tax charges incurred from coal contract modifications	'	29,000,000	'
Hydroelectric License Commitments (Numeric) [Abstract]	'	'	'
Number of hydroelectric facilities owned by PPL Montana	11	'	'
Number of storage reservoirs owned by PPL Montana	1	'	'
Total term, in years, of the Kerr Dam project license	50	'	'
Term, in years, PPL Montana is required to operate the Kerr Dam project	30	'	'
Number of open Memoranda of Understanding related to the issuance of the renewal license for the Missouri-Madison project	2	'	'
Number of dams related to the Missouri-Madison project for which Memoranda of Understanding exists	9	'	'
Estimate Of Remaining Commitment On Specific Missouri Madison Project	29,000,000	'	'
Number of hydroelectric facilities owned by PPL Montana to be sold	11	'	'
Legal Matters - Montana Hydroelectric Litigation (Numeric) [Abstract]	'	'	'
Contingency reversal during period, impact to Operation and Maintenance	'	'	65,000,000
Contingency reversal during period, impact to interest expense	'	'	10,000,000
Legal Matters - Bankruptcy of Southern Montana Electric Generation and Transmission Cooperative, Inc. (Numeric) [Abstract]	'	'	'
Reserve related to the accounts receivable from a bankrupt counterparty	'	21,000,000	'
Total unsecured claim as a result of the termination of the SMGT contract	'	375,000,000	'
Legal Matters - Sierra Club Litigation (Numeric) [Abstract]	'	'	'
Number of separate claims included in the original complaint against PPL Montana	39	'	'
Number of original claims against Colstrip that did not allege Prevention of Significant Deterioration but alleged Title V operating permit violations	3	'	'
Average requested amount, per day per violation, of injuctive relief and civil penalities	36,000,000	'	'
Amount of civil penalities to be used for beneficial mitigation projects	100,000,000	'	'
Estimated number of post-2000 projects alleged not to be in compliance with the Clean Air Act	40	'	'
Regulatory Issues - Maryland Capacity Order (Numeric) [Abstract]	'	'	'
Number electric utilities ordered to enter into long term contracts	3	'	'
Capacity of natural gas-fired combined-cycle generating facility (in MW)	661	'	'
Regulatory Issues - Pacific Northwest Markets (Numeric) [Abstract]	'	'	'
Settlement amount reached with one of the parties	'	75,000	'
Amount of claim sought by City of Tacoma	'	23,000,000	'
Amount for claims remaining unsettled at period end	50,000,000	'	'
Regulatory Issues - FERC Market-Based Rate Authority (Numeric) [Abstract]	'	'	'
Time from December 1998 that a subsidiary was required to respond to the FERC market analysis information request (in years)	3	'	'
Frequency, after initial filing, that a subsidiary is required to respond to the FERC market analysis information request (in years)	3	'	'
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]	'	'	'
Maximum per day penalties for reliability violations	1,000,000	'	'
Settled Litigation - Spent Nuclear Fuel Litigation (Numeric) [Abstract]	'	'	'
PPL's share of settlement for spent nuclear fuel litigation	'	'	56,000,000
PPL Electric Utilities Corp [Member]	'	'	'
Energy Purchase Commitments (Numeric) [Abstract]	'	'	'
Frequency of competitive solicitations each plan year	'twice	'	'
Shortest term of layered short-term full requirement products (in months)	3	'	'
Longest term of layered short-term full requirement products (in months)	12	'	'
Recurring term of spot market product (in months)	12	'	'
Number of competitive solicitations completed to date under the Public Utility Commission approved purchase plan	2	'	'
Total number of competitive solicitations under the Public Utility Commission approved purchase plan	4	'	'
Regulatory Issues - Maryland Capacity Order (Numeric) [Abstract]	'	'	'
Number electric utilities ordered to enter into long term contracts	3	'	'
Capacity of natural gas-fired combined-cycle generating facility (in MW)	661	'	'
Regulatory Issues - FERC Market-Based Rate Authority (Numeric) [Abstract]	'	'	'
Time from December 1998 that a subsidiary was required to respond to the FERC market analysis information request (in years)	3	'	'
Frequency, after initial filing, that a subsidiary is required to respond to the FERC market analysis information request (in years)	3	'	'
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]	'	'	'
Maximum per day penalties for reliability violations	1,000,000	'	'
LG And E And KU Energy LLC [Member]	'	'	'
Regulatory Issues - FERC Market-Based Rate Authority (Numeric) [Abstract]	'	'	'
Time from December 1998 that a subsidiary was required to respond to the FERC market analysis information request (in years)	3	'	'
Frequency, after initial filing, that a subsidiary is required to respond to the FERC market analysis information request (in years)	3	'	'
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]	'	'	'
Maximum per day penalties for reliability violations	1,000,000	'	'
LG And E And KU Energy LLC [Member] | Power Purchase [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
2014	26,000,000	'	'
2015	26,000,000	'	'
2016	26,000,000	'	'
2017	27,000,000	'	'
2018	29,000,000	'	'
Thereafter	728,000,000	'	'
Total future obligation	862,000,000	'	'
Purchases	26,000,000	29,000,000	32,000,000
Louisville Gas And Electric Co [Member]	'	'	'
Regulatory Issues - FERC Market-Based Rate Authority (Numeric) [Abstract]	'	'	'
Time from December 1998 that a subsidiary was required to respond to the FERC market analysis information request (in years)	3	'	'
Frequency, after initial filing, that a subsidiary is required to respond to the FERC market analysis information request (in years)	3	'	'
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]	'	'	'
Maximum per day penalties for reliability violations	1,000,000	'	'
Louisville Gas And Electric Co [Member] | Power Purchase [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
2014	18,000,000	'	'
2015	18,000,000	'	'
2016	18,000,000	'	'
2017	19,000,000	'	'
2018	20,000,000	'	'
Thereafter	504,000,000	'	'
Total future obligation	597,000,000	'	'
Purchases	18,000,000	20,000,000	22,000,000
Kentucky Utilities Co [Member]	'	'	'
Regulatory Issues - FERC Market-Based Rate Authority (Numeric) [Abstract]	'	'	'
Time from December 1998 that a subsidiary was required to respond to the FERC market analysis information request (in years)	3	'	'
Frequency, after initial filing, that a subsidiary is required to respond to the FERC market analysis information request (in years)	3	'	'
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]	'	'	'
Maximum per day penalties for reliability violations	1,000,000	'	'
Kentucky Utilities Co [Member] | Power Purchase [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
2014	8,000,000	'	'
2015	8,000,000	'	'
2016	8,000,000	'	'
2017	8,000,000	'	'
2018	9,000,000	'	'
Thereafter	224,000,000	'	'
Total future obligation	265,000,000	'	'
Purchases	$8,000,000	$9,000,000	$10,000,000

Commitments_and_Contingencies_2

Commitments and Contingencies (Environmental Matter and Other) (Details) (USD $)	1 Months Ended	12 Months Ended
	Jan. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
		MW	T
		mi
		Y
		lb
		T
		Integer
Environmental Matters - Domestic - Air - Cross State Air Pollution Rule (formerly Clean Air Transport Rule) and Clean Air Interstate Rule (Numeric) [Abstract]	'	'	'
Number of phases CSAPR will be implemented	'	2	'
Environmental Matters - Domestic - Air - National Ambient Air Quality Standards [Abstract]	'	'	'
Standard for sulfur dioxide emissions (in hours)	'	1	'
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]	'	'	'
Period for compliance with final MACT standards (in years)	'	3	'
Possible period of extension to comply with final MACT standards (in years)	'	1	'
Environmental Matters - Domestic - Air - Cane Run Environmental Claims (Numeric) [Abstract]	'	'	'
Number of residents that notified of intention to file class action suit	'	2	'
Number of residents that filed class action suit	'	6	'
Number of miles within plant that would include a class of residents	'	4	'
Environmental Matters - Domestic - Air - Greenhouse Gas Regulations and Tort Litigation (Numeric) [Abstract]	'	'	'
Percentage reduction of greenhouse gas emissions below 2005 levels by 2020	'	17.00%	'
Estimate of "social cost of carbon" per metric ton prior to 2015	'	23.8	'
Estimate of "social cost of carbon" per metric ton in 2015	'	38	'
Number of northeastern states that signed a Memorandum of Understanding that established Regional Greenhouse Gas Initiative	'	10	'
Minimum capacity of electric power plants that are impacted by Regional Greenhouse Gas Initiative's emissions stabilization program (in MW)	'	25	'
Percentage reduction by 2019 in carbon dioxide emissions under Regional Greenhouse Gas Initiative	'	10.00%	'
Maximum percentage in greenhouse gas emissions by implementing actions identified in Pennsylvania report	'	30.00%	'
Number of electric utility companies affected by a September 2009 U.S. Court of Appeals for the Second Circuit decision	'	5	'
Number of companies cited in May 2011 Mississippi court filing	'	87	'
Number of indirect subsidaries cited in a May 2011 Mississippi court filing	'	3	'
Carbon dioxide emitted from PPL power plants during the reporting period (in tons)	'	62,000,000	70,000,000
Number of pounds in a ton of carbon dioxide emissions	'	2,000	'
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]	'	'	'
Proposed amount of funding for solar projects	'	$25,000,000	'
Current percentage for Maryland renewable portfolio standard requirements	'	20.00%	'
Proposed percentage for Maryland renewable portfolio standard requirements	40.00%	'	'
Environmental Matters - Domestic - Water/Waste - Coal Combustion Residuals (Numeric) [Abstract]	'	'	'
Number of approaches proposed by EPA in June 2010 to regulate CCRs	'	2	'
Number of companies that have filed a lawsuits against the EPA	'	2	'
Environmental Matters - Domestic - Water/Waste - Seepages and Groundwater Infiltration - Pennsylvania, Montana and Kentucky (Numeric) [Abstract]	'	'	'
Period for PPL Montana to provide financial assurance to Montana Department of Environmental Quality (in years)	'	5	'
Environmental Matters - Domestic - Water/Waste - Clean Water Act 316(b) (Numeric) [Abstract]	'	'	'
Number of requirements under proposed EPA rule regarding reducing impact to aquatic organisms	'	2	'
Number of factors to make a site-specific determination	'	9	'
Environmental Matters - Domestic - Superfund and Other Remediation (Numeric) [Abstract]	'	'	'
Period end recorded discounted liability for the cost of pumping and treating groundwater, and operating and maintaining a passive wetlands treatment center	'	21,000,000	'
Period of years used to calculate discounted environmental liability	'	50	'
Weighted average discount rate applied to calculate the liability (in hundredths)	'	8.21%	'
Expected undiscounted payments per year related to pumping and treating groundwater, and operating and maintaining a passive wetlands treatment center for each of the years 2014 through 2018	'	1,000,000	'
Expected undiscounted payments per year related to pumping and treating groundwater, and operating and maintaining a passive wetlands treatment center after 2018	'	107,000,000	'
Other - Nuclear Insurance (Numeric) [Abstract]	'	'	'
Maximum public liability for claims resulting an incident at nuclear station	'	13,600,000,000	'
Maximum amount that could be assessed resulting from an incident at nuclear station	'	255,000,000	'
Maximum amount payable per year resulting from an incident at nuclear station	'	38,000,000	'
Maximum amount of insured property damage losses at nuclear station	'	2,500,000,000	'
Maximum assessment for retroactive premiums for nuclear outage insurance coverage	'	46,000,000	'
Workforce Subject To Collective Bargaining Agreement [Member]	'	'	'
Other - Labor Unions (Details) [Line Items]	'	'	'
Number of employees	'	3,755	'
Percent of total workforce	'	20.00%	'
PPL Energy Supply LLC [Member]	'	'	'
Environmental Matters - Domestic - Air - Cross State Air Pollution Rule (formerly Clean Air Transport Rule) and Clean Air Interstate Rule (Numeric) [Abstract]	'	'	'
Number of phases CSAPR will be implemented	'	2	'
Environmental Matters - Domestic - Air - National Ambient Air Quality Standards [Abstract]	'	'	'
Standard for sulfur dioxide emissions (in hours)	'	1	'
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]	'	'	'
Period for compliance with final MACT standards (in years)	'	3	'
Possible period of extension to comply with final MACT standards (in years)	'	1	'
Environmental Matters - Domestic - Air - Greenhouse Gas Regulations and Tort Litigation (Numeric) [Abstract]	'	'	'
Percentage reduction of greenhouse gas emissions below 2005 levels by 2020	'	17.00%	'
Estimate of "social cost of carbon" per metric ton prior to 2015	'	23.8	'
Estimate of "social cost of carbon" per metric ton in 2015	'	38	'
Number of northeastern states that signed a Memorandum of Understanding that established Regional Greenhouse Gas Initiative	'	10	'
Minimum capacity of electric power plants that are impacted by Regional Greenhouse Gas Initiative's emissions stabilization program (in MW)	'	25	'
Percentage reduction by 2019 in carbon dioxide emissions under Regional Greenhouse Gas Initiative	'	10.00%	'
Maximum percentage in greenhouse gas emissions by implementing actions identified in Pennsylvania report	'	30.00%	'
Carbon dioxide emitted from PPL power plants during the reporting period (in tons)	'	26,000,000	'
Number of pounds in a ton of carbon dioxide emissions	'	2,000	'
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]	'	'	'
Proposed amount of funding for solar projects	'	25,000,000	'
Current percentage for Maryland renewable portfolio standard requirements	'	20.00%	'
Proposed percentage for Maryland renewable portfolio standard requirements	40.00%	'	'
Environmental Matters - Domestic - Water/Waste - Coal Combustion Residuals (Numeric) [Abstract]	'	'	'
Number of approaches proposed by EPA in June 2010 to regulate CCRs	'	2	'
Number of companies that have filed a lawsuits against the EPA	'	2	'
Environmental Matters - Domestic - Water/Waste - Seepages and Groundwater Infiltration - Pennsylvania, Montana and Kentucky (Numeric) [Abstract]	'	'	'
Period for PPL Montana to provide financial assurance to Montana Department of Environmental Quality (in years)	'	5	'
Environmental Matters - Domestic - Water/Waste - Clean Water Act 316(b) (Numeric) [Abstract]	'	'	'
Number of requirements under proposed EPA rule regarding reducing impact to aquatic organisms	'	2	'
Number of factors to make a site-specific determination	'	9	'
Environmental Matters - Domestic - Superfund and Other Remediation (Numeric) [Abstract]	'	'	'
Period end recorded discounted liability for the cost of pumping and treating groundwater, and operating and maintaining a passive wetlands treatment center	'	21,000,000	'
Period of years used to calculate discounted environmental liability	'	50	'
Weighted average discount rate applied to calculate the liability (in hundredths)	'	8.21%	'
Expected undiscounted payments per year related to pumping and treating groundwater, and operating and maintaining a passive wetlands treatment center for each of the years 2014 through 2018	'	1,000,000	'
Expected undiscounted payments per year related to pumping and treating groundwater, and operating and maintaining a passive wetlands treatment center after 2018	'	107,000,000	'
Other - Nuclear Insurance (Numeric) [Abstract]	'	'	'
Maximum public liability for claims resulting an incident at nuclear station	'	13,600,000,000	'
Maximum amount that could be assessed resulting from an incident at nuclear station	'	255,000,000	'
Maximum amount payable per year resulting from an incident at nuclear station	'	38,000,000	'
Maximum amount of insured property damage losses at nuclear station	'	2,500,000,000	'
Maximum assessment for retroactive premiums for nuclear outage insurance coverage	'	46,000,000	'
PPL Energy Supply LLC [Member] | Workforce Subject To Collective Bargaining Agreement [Member]	'	'	'
Other - Labor Unions (Details) [Line Items]	'	'	'
Number of employees	'	1,190	'
Percent of total workforce	'	24.00%	'
PPL Electric Utilities Corp [Member]	'	'	'
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]	'	'	'
Current percentage for Maryland renewable portfolio standard requirements	'	20.00%	'
Proposed percentage for Maryland renewable portfolio standard requirements	40.00%	'	'
PPL Electric Utilities Corp [Member] | Workforce Subject To Collective Bargaining Agreement [Member]	'	'	'
Other - Labor Unions (Details) [Line Items]	'	'	'
Number of employees	'	1,419	'
Percent of total workforce	'	63.00%	'
LG And E And KU Energy LLC [Member]	'	'	'
Environmental Matters - Domestic - Air - Cross State Air Pollution Rule (formerly Clean Air Transport Rule) and Clean Air Interstate Rule (Numeric) [Abstract]	'	'	'
Number of phases CSAPR will be implemented	'	2	'
Environmental Matters - Domestic - Air - National Ambient Air Quality Standards [Abstract]	'	'	'
Standard for sulfur dioxide emissions (in hours)	'	1	'
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]	'	'	'
Period for compliance with final MACT standards (in years)	'	3	'
Possible period of extension to comply with final MACT standards (in years)	'	1	'
Environmental Matters - Domestic - Air - Cane Run Environmental Claims (Numeric) [Abstract]	'	'	'
Number of residents that notified of intention to file class action suit	'	2	'
Number of residents that filed class action suit	'	6	'
Number of miles within plant that would include a class of residents	'	4	'
Environmental Matters - Domestic - Air - Greenhouse Gas Regulations and Tort Litigation (Numeric) [Abstract]	'	'	'
Percentage reduction of greenhouse gas emissions below 2005 levels by 2020	'	17.00%	'
Estimate of "social cost of carbon" per metric ton prior to 2015	'	23.8	'
Estimate of "social cost of carbon" per metric ton in 2015	'	38	'
Number of electric utility companies affected by a September 2009 U.S. Court of Appeals for the Second Circuit decision	'	5	'
Number of companies cited in May 2011 Mississippi court filing	'	87	'
Number of indirect subsidaries cited in a May 2011 Mississippi court filing	'	3	'
Carbon dioxide emitted from LKE power plants during the reporting period (in tons)	'	36,000,000	'
Number of pounds in a ton of carbon dioxide emissions	'	2,000	'
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]	'	'	'
Proposed amount of funding for solar projects	'	25,000,000	'
Current percentage for Maryland renewable portfolio standard requirements	'	20.00%	'
Proposed percentage for Maryland renewable portfolio standard requirements	40.00%	'	'
Environmental Matters - Domestic - Water/Waste - Coal Combustion Residuals (Numeric) [Abstract]	'	'	'
Number of approaches proposed by EPA in June 2010 to regulate CCRs	'	2	'
Number of companies that have filed a lawsuits against the EPA	'	2	'
Environmental Matters - Domestic - Water/Waste - Clean Water Act 316(b) (Numeric) [Abstract]	'	'	'
Number of requirements under proposed EPA rule regarding reducing impact to aquatic organisms	'	2	'
Number of factors to make a site-specific determination	'	9	'
LG And E And KU Energy LLC [Member] | Workforce Subject To Collective Bargaining Agreement [Member]	'	'	'
Other - Labor Unions (Details) [Line Items]	'	'	'
Number of employees	'	774	'
Percent of total workforce	'	22.00%	'
Louisville Gas And Electric Co [Member]	'	'	'
Environmental Matters - Domestic - Air - Cross State Air Pollution Rule (formerly Clean Air Transport Rule) and Clean Air Interstate Rule (Numeric) [Abstract]	'	'	'
Number of phases CSAPR will be implemented	'	2	'
Environmental Matters - Domestic - Air - National Ambient Air Quality Standards [Abstract]	'	'	'
Standard for sulfur dioxide emissions (in hours)	'	1	'
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]	'	'	'
Period for compliance with final MACT standards (in years)	'	3	'
Possible period of extension to comply with final MACT standards (in years)	'	1	'
Environmental Matters - Domestic - Air - Cane Run Environmental Claims (Numeric) [Abstract]	'	'	'
Number of residents that notified of intention to file class action suit	'	2	'
Number of residents that filed class action suit	'	6	'
Number of miles within plant that would include a class of residents	'	4	'
Environmental Matters - Domestic - Air - Greenhouse Gas Regulations and Tort Litigation (Numeric) [Abstract]	'	'	'
Percentage reduction of greenhouse gas emissions below 2005 levels by 2020	'	17.00%	'
Estimate of "social cost of carbon" per metric ton prior to 2015	'	23.8	'
Estimate of "social cost of carbon" per metric ton in 2015	'	38	'
Carbon dioxide emitted from LKE power plants during the reporting period (in tons)	'	17,000,000	'
Number of pounds in a ton of carbon dioxide emissions	'	2,000	'
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]	'	'	'
Proposed amount of funding for solar projects	'	25,000,000	'
Current percentage for Maryland renewable portfolio standard requirements	'	20.00%	'
Proposed percentage for Maryland renewable portfolio standard requirements	40.00%	'	'
Environmental Matters - Domestic - Water/Waste - Coal Combustion Residuals (Numeric) [Abstract]	'	'	'
Number of approaches proposed by EPA in June 2010 to regulate CCRs	'	2	'
Number of companies that have filed a lawsuits against the EPA	'	2	'
Environmental Matters - Domestic - Water/Waste - Clean Water Act 316(b) (Numeric) [Abstract]	'	'	'
Number of requirements under proposed EPA rule regarding reducing impact to aquatic organisms	'	2	'
Number of factors to make a site-specific determination	'	9	'
Louisville Gas And Electric Co [Member] | Workforce Subject To Collective Bargaining Agreement [Member]	'	'	'
Other - Labor Unions (Details) [Line Items]	'	'	'
Number of employees	'	701	'
Percent of total workforce	'	70.00%	'
Kentucky Utilities Co [Member]	'	'	'
Environmental Matters - Domestic - Air - Cross State Air Pollution Rule (formerly Clean Air Transport Rule) and Clean Air Interstate Rule (Numeric) [Abstract]	'	'	'
Number of phases CSAPR will be implemented	'	2	'
Environmental Matters - Domestic - Air - National Ambient Air Quality Standards [Abstract]	'	'	'
Standard for sulfur dioxide emissions (in hours)	'	1	'
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]	'	'	'
Period for compliance with final MACT standards (in years)	'	3	'
Possible period of extension to comply with final MACT standards (in years)	'	1	'
Environmental Matters - Domestic - Air - Greenhouse Gas Regulations and Tort Litigation (Numeric) [Abstract]	'	'	'
Percentage reduction of greenhouse gas emissions below 2005 levels by 2020	'	17.00%	'
Estimate of "social cost of carbon" per metric ton prior to 2015	'	23.8	'
Estimate of "social cost of carbon" per metric ton in 2015	'	38	'
Number of electric utility companies affected by a September 2009 U.S. Court of Appeals for the Second Circuit decision	'	5	'
Number of companies cited in May 2011 Mississippi court filing	'	87	'
Carbon dioxide emitted from LKE power plants during the reporting period (in tons)	'	19,000,000	'
Number of pounds in a ton of carbon dioxide emissions	'	2,000	'
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]	'	'	'
Proposed amount of funding for solar projects	'	$25,000,000	'
Current percentage for Maryland renewable portfolio standard requirements	'	20.00%	'
Proposed percentage for Maryland renewable portfolio standard requirements	40.00%	'	'
Environmental Matters - Domestic - Water/Waste - Coal Combustion Residuals (Numeric) [Abstract]	'	'	'
Number of approaches proposed by EPA in June 2010 to regulate CCRs	'	2	'
Number of companies that have filed a lawsuits against the EPA	'	2	'
Environmental Matters - Domestic - Water/Waste - Clean Water Act 316(b) (Numeric) [Abstract]	'	'	'
Number of requirements under proposed EPA rule regarding reducing impact to aquatic organisms	'	2	'
Number of factors to make a site-specific determination	'	9	'
Kentucky Utilities Co [Member] | Workforce Subject To Collective Bargaining Agreement [Member]	'	'	'
Other - Labor Unions (Details) [Line Items]	'	'	'
Number of employees	'	73	'
Percent of total workforce	'	7.00%	'

Commitments_and_Contingencies_3

Commitments and Contingencies (Guarantees and Other Assurances) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

In Millions, unless otherwise specified

Indemnification Guarantee [Member]

PPL Guarantee [Member]

PPL Guarantee [Member]

PPL Guarantee [Member]

PPL Energy Supply Guarantee [Member]

PPL Energy Supply Guarantee [Member]

PPL Electric Guarantee [Member]

LKE Guarantee [Member]

LGE And KU Guarantee [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

PPL Electric Utilities Corp [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Indemnifications For Entities In Liquidation Sales Of Assets [Member]

Indemnification Guarantee [Member]

Indemnification Guarantee [Member]

Financial Guarantee [Member]

Indemnification Guarantee [Member]

Financial Guarantee [Member]

Indemnification Guarantee [Member]

Indemnification Guarantee [Member]

Financial Guarantee [Member]

Indemnification Guarantee [Member]

Financial Guarantee [Member]

Financial Guarantee [Member]

Indemnification Guarantee [Member]

Indemnification Guarantee [Member]

LGE And KU Guarantee [Member]

Financial Guarantee [Member]

LGE And KU Guarantee [Member]

Financial Guarantee [Member]

LGE And KU Guarantee [Member]

Indemnifications Related To WPD Midlands Acquisition [Member]

Indemnifications For Entities In Liquidation Sales Of Assets [Member]

WPD Guarantee Of Pension And Other Obligations Of Unconsolidated Entities [Member]

Indemnifications For Sales Of Assets [Member]

Guarantee Of Portion Of Divested Unconsolidated Entitys Debt [Member]

Guarantee Of Inventory Value [Member]

Indemnification Of Lease Termination And Other Divestitures [Member]

LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Indemnifications For Sales Of Assets [Member]

Letters Of Credit Issued On Behalf Of Affiliates [Member]

Guarantee Of Portion Of Divested Unconsolidated Entitys Debt [Member]

Guarantee Of Inventory Value [Member]

Indemnification Of Lease Termination And Other Divestitures [Member]

Financial Guarantee [Member]

LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Financial Guarantee [Member]

LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Financial Guarantee [Member]

Integer

LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Guarantor Obligations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Recorded liability for all guarantees

$26

$24

'

'

'

'

'

'

'

'

'

'

'

'

'

$19

$20

'

'

'

'

'

'

Maximum exposure

'

'

'

'

12

[1]

127

[2]

250

[3]

22

[4]

27

[5]

301

[6]

'

250

[3]

29

[7]

22

[4]

27

[5]

'

'

301

[6]

'

'

'

'

'

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.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchases Commitments" above for additional information on the OVEC power purchase contract.

'The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchases Commitments" above for additional information on the OVEC power purchase contract.

'

'The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchases Commitments" above for additional information on the OVEC power purchase contract.

'

Expiration date

'

'

'

'

'

'

'2025

'2018

'2017

'

'

'2025

'

'2018

'2017

'

'

'

'

'

'

'

'

Expiration date minimum

'

'

'2017

'

'

'

'

'

'

'2021

'

'

'2014

'

'

'

'

'2021

'

'

'

'

'

Expiration date maximum

'

'

'2018

'

'

'

'

'

'

'2023

'

'

'2015

'

'

'

'

'2023

'

'

'

'

'

Minimum period that indemnifications generally expire (in years)

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum period that indemnifications generally expire (in years)

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity interest in previously owned facility (in hundredths)

'

'

'

'

'

'

'

33.00%

'

'

'

'

'

33.00%

'

'

'

'

'

'

'

'

'

Term of guarantee (in years)

'

'

'

'

'

'

'

'

'

'12

'

'

'

'

'

'

'

'12

'

'

'

'

'

Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues

'

'

'

'

'

'

'

'

'

200

'

'

'

'

'

'

'

200

'

'

'

'

'

Maximum exposure of other guarantees expiring related to a terminated lease

'

'

'

'

'

'

'

'

'

100

'

'

'

'

'

'

'

100

'

'

'

'

'

Charge recorded in discontinued operations relating to certain indemnification, pre-tax

'

'

'

'

'

'

'

'

'

9

'

'

'

'

'

'

'

9

'

'

'

'

'

Charge recorded in discontinued operations relating to certain indemnification, after-tax

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

5

'

'

'

'

'

Contingent potential proportionate share of OVEC's outstanding debt

'

'

'

'

'

'

'

'

'

'

129

'

'

'

'

'

'

'

129

'

89

'

40

Other Guarantee (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum aggregate coverage bodily injury and property damage

$225

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[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 either prior or subsequent to liquidation or is 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 electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At December 31, 2013, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.

[3]

Indemnifications are governed by the specific sales agreement and include breach of the representations, warranties and covenants, and liabilities for certain other matters. PPL Energy Supply's maximum exposure with respect to certain indemnifications and the expiration of the indemnifications cannot be estimated because the maximum potential liability is not capped by the transaction documents and the expiration date is based on the applicable statute of limitations. The exposure and expiration date noted is based on those cases in which the agreements provide for specific limits.

[4]

Relates to a guarantee of one-third of the divested entity's debt. The purchaser provided a cross-indemnity, secured by a lien on the purchaser's stock of the divested entity. The exposure noted reflects principal only.

[5]

A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold.

[6]

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 guarantees is the LKE guarantee covering operational, regulatory and environmental commitments 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 fall outside the cumulative cap. LKE has contested the applicability of the indemnification requirement relating to one matter presented by a counterparty under this guarantee. Another guarantee with a maximum exposure of $100 million covering other indemnifications expires in 2023. In May 2012, LKE's indemnitee received an arbitration panel's decision affecting this matter, which granted LKE’s indemnitee certain rights of first refusal to purchase excess power at a market-based price rather than at an absolute fixed price. In January 2013, LKE's indemnitee commenced a proceeding in the Kentucky Court of Appeals appealing the December 2012 order of the Henderson Circuit Court, confirming the arbitration award. A decision in the appellate matter may occur during 2014. LKE believes its indemnification obligations in this matter remain subject to various uncertainties, including potential for additional legal challenges regarding the arbitration decision as well as future prices, availability and demand for the subject excess power. LKE continues to evaluate various legal and commercial options with respect to this indemnification matter. The ultimate outcomes of the WKE termination-related indemnifications cannot be predicted at this time. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum; however, LKE is not aware of formal claims under such indemnities made by any party at this time. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. In the second quarter of 2012, LKE adjusted its estimated liability for certain of these indemnifications by $9 million ($5 million after-tax), which is reflected in "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statement of Income. The adjustment was recorded in the Kentucky Regulated segment for PPL. LKE cannot predict the ultimate outcomes of such indemnification circumstances, but does not currently expect such outcomes to result in significant losses above the amounts recorded.

[7]

Standby letter of credit arrangements under PPL Energy Supply's credit facilities for the purposes of protecting various third parties against nonperformance by PPL. This is not a guarantee by PPL on a consolidated basis

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
PPL Energy Supply LLC [Member]	'	'	'
Support Costs (Details) [Abstract]	'	'	'
Support cost allocations from subsidiary of parent to registrant	$218	$212	$189
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Interest earned on the borrowings	3	2	8
PPL Energy Supply LLC [Member] | PPL Electric [Member]	'	'	'
PLR Contracts/Purchase of Accounts Receivable (Numeric) [Abstract]	'	'	'
Credit limit with affiliate under a Master Supply Agreement	20	'	'
Credit exposure with affiliate under a Master Supply Agreement	28	'	'
PPL Energy Supply LLC [Member] | PPL Energy Funding [Member]	'	'	'
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Intercompany borrowings demand note rate on outstanding borrowing	'	'	3.77%
PPL Energy Supply LLC [Member] | Certain Affiliates [Member]	'	'	'
Trademark Royalties (Numeric) [Abstract]	'	'	'
Trademark royalty license expense	'	'	40
PPL Electric Utilities Corp [Member]	'	'	'
Support Costs (Details) [Abstract]	'	'	'
Support cost allocations from subsidiary of parent to registrant	146	157	145
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Notes receivable from affiliates	150	'	'
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]	'	'	'
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Notes receivable from affiliates	150	'	'
Intercompany borrowings demand note rate on outstanding borrowing	1.92%	'	'
LG And E And KU Energy LLC [Member]	'	'	'
Support Costs (Details) [Abstract]	'	'	'
Support cost allocations from subsidiary of parent to registrant	15	15	16
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Notes receivable from affiliates	70	'	'
Notes payable to affiliates	'	25	'
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]	'	'	'
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Intercompany borrowings demand note rate on outstanding borrowing	'	1.71%	'
Intercompany note with affiliate maximum borrowing capacity	225	'	'
Amount of capacity reduction to existing affiliate credit facility	75	'	'
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]	'	'	'
Intercompany Borrowings (Numeric) [Abstract]	'	'	'
Intercompany borrowings demand note rate on outstanding borrowing	2.17%	'	'
Intercompany note with affiliate maximum borrowing capacity	300	'	'
Louisville Gas And Electric Co [Member]	'	'	'
Intercompany Billings by LKS (Details) [Abstract]	'	'	'
Intercompany billings between affiliates	216	186	190
Kentucky Utilities Co [Member]	'	'	'
Intercompany Billings by LKS (Details) [Abstract]	'	'	'
Intercompany billings between affiliates	$207	$161	$204

Other_Income_Expense_net_Detai

Other Income (Expense) - net (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Income [Line Items]	'	'	'
Earnings on securities in nuclear decommissioning trust funds	$23	$22	$24
Interest income	3	5	7
Allowance for funds used during construction - equity component	10	10	7
Net hedge gains associated with the 2011 Bridge Facility	'	'	55	[1]
Gain on redemption of debt	'	'	22	[2]
Earnings (losses) from equity method investments	'	-8	1
Miscellaneous - Domestic	18	11	10
Miscellaneous - United Kingdom	'	2	1
Other income	54	42	127
Other Expense [Line Items]	'	'	'
Economic foreign currency exchange contracts	38	52	-10
Charitable contributions	25	10	9
WPD Midlands acquisition-related costs	'	'	34
Foreign currency loss on 2011 Bridge Facility	'	'	57
United Kingdom stamp duty tax	'	'	21
Miscellaneous - Domestic	12	16	9
Miscellaneous - United Kingdom	2	3	3
Other expense	77	81	123
Other Income (Expense) - net	-23	-39	4
Extinguishment of notes [Abstract]	'	'	'
Interest rate on debt related to discontinuance of fair value hedge	'	'	7.13%
PPL Energy Supply LLC [Member]	'	'	'
Other Income [Line Items]	'	'	'
Earnings on securities in nuclear decommissioning trust funds	23	22	24
Interest income	'	1	1
Miscellaneous - Domestic	14	5	6
Other income	37	28	31
Other Expense [Line Items]	'	'	'
Charitable contributions	4	3	3
Miscellaneous - Domestic	3	7	5
Other expense	7	10	8
Other Income (Expense) - net	30	18	23
PPL Electric Utilities Corp [Member]	'	'	'
Other Expense [Line Items]	'	'	'
Other Income (Expense) - net	6	9	7
LG And E And KU Energy LLC [Member]	'	'	'
Other Expense [Line Items]	'	'	'
Other Income (Expense) - net	-7	-15	-1
Louisville Gas And Electric Co [Member]	'	'	'
Other Expense [Line Items]	'	'	'
Other Income (Expense) - net	-2	-3	-2
Kentucky Utilities Co [Member]	'	'	'
Other Expense [Line Items]	'	'	'
Other Income (Expense) - net	($3)	($8)	($1)
[1]	Represents a gain on foreign currency contracts that hedged the repayment of the 2011 Bridge Facility borrowing.
[2]	In July 2011, as a result of PPL Electric’s redemption of 7.125% Senior Secured Bonds due 2013, PPL recorded a gain on the accelerated amortization of the fair value adjustment to the debt recorded in connection with previously settled fair value hedges.

Fair_Value_Measurements_and_Cr3

Fair Value Measurements and Credit Concentration (Assets and Liabilities Measured on Recurring Basis Table) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Price risk management liabilities:	'		'
Total price risk management liabilities	$1,244		$1,694
Recurring [Member]	'		'
Assets	'		'
Cash and cash equivalents	1,102		901
Restricted cash and cash equivalents	156	[1]	135	[1]
Price risk management assets:	'		'
Energy commodities assets	1,188		2,068
Interest rate swaps assets	91		15
Cross-currency swaps assets	'		14
Total price risk management assets	1,279		2,097
NDT funds	864		712
Auction rate securities	19	[2]	19	[2]
Total assets	3,420		3,864
Price risk management liabilities:	'		'
Energy commodities liabilities	1,070		1,566
Interest rate swaps liabilities	36		80
Foreign currency contracts liabilities	106		44
Cross-currency swaps liabilities	32		4
Total price risk management liabilities	1,244		1,694
Recurring [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	14		11
Recurring [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	547		412
Recurring [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	81		60
Recurring [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	95		95
Recurring [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	6		9
Recurring [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	77		82
Recurring [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	38		40
Recurring [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	5		3
Recurring [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	1		'
Recurring [Member] | Level 1 [Member]	'		'
Assets	'		'
Cash and cash equivalents	1,102		901
Restricted cash and cash equivalents	156	[1]	135	[1]
Price risk management assets:	'		'
Energy commodities assets	3		2
Interest rate swaps assets	'		'
Cross-currency swaps assets	'		'
Total price risk management assets	3		2
NDT funds	550		437
Auction rate securities	'		'
Total assets	1,811		1,475
Price risk management liabilities:	'		'
Energy commodities liabilities	4		2
Interest rate swaps liabilities	'		'
Foreign currency contracts liabilities	'		'
Cross-currency swaps liabilities	'		'
Total price risk management liabilities	4		2
Recurring [Member] | Level 1 [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	14		11
Recurring [Member] | Level 1 [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	409		308
Recurring [Member] | Level 1 [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	33		25
Recurring [Member] | Level 1 [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	95		95
Recurring [Member] | Level 1 [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 1 [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 1 [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 1 [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 1 [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	-1		-2
Recurring [Member] | Level 2 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Energy commodities assets	1,123		2,037
Interest rate swaps assets	91		15
Cross-currency swaps assets	'		13
Total price risk management assets	1,214		2,065
NDT funds	314		275
Auction rate securities	'		3
Total assets	1,528		2,343
Price risk management liabilities:	'		'
Energy commodities liabilities	1,028		1,557
Interest rate swaps liabilities	36		80
Foreign currency contracts liabilities	106		44
Cross-currency swaps liabilities	32		4
Total price risk management liabilities	1,202		1,685
Recurring [Member] | Level 2 [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 2 [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	138		104
Recurring [Member] | Level 2 [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	48		35
Recurring [Member] | Level 2 [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 2 [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	6		9
Recurring [Member] | Level 2 [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	77		82
Recurring [Member] | Level 2 [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	38		40
Recurring [Member] | Level 2 [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	5		3
Recurring [Member] | Level 2 [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	2		2
Recurring [Member] | Level 3 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Energy commodities assets	62		29
Interest rate swaps assets	'		'
Cross-currency swaps assets	'		1
Total price risk management assets	62		30
NDT funds	'		'
Auction rate securities	19	[2]	16	[2]
Total assets	81		46
Price risk management liabilities:	'		'
Energy commodities liabilities	38		7
Interest rate swaps liabilities	'		'
Foreign currency contracts liabilities	'		'
Cross-currency swaps liabilities	'		'
Total price risk management liabilities	38		7
Recurring [Member] | Level 3 [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
Recurring [Member] | Level 3 [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member]	'		'
Assets	'		'
Cash and cash equivalents	239		413
Restricted cash and cash equivalents	85	[1]	63	[1]
Price risk management assets:	'		'
Energy commodities assets	1,188		2,068
Total price risk management assets	1,188		2,068
NDT funds	864		712
Auction rate securities	16	[2]	16	[2]
Total assets	2,392		3,272
Price risk management liabilities:	'		'
Energy commodities liabilities	1,070		1,566
Total price risk management liabilities	1,070		1,566
PPL Energy Supply LLC [Member] | Recurring [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	14		11
PPL Energy Supply LLC [Member] | Recurring [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	547		412
PPL Energy Supply LLC [Member] | Recurring [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	81		60
PPL Energy Supply LLC [Member] | Recurring [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	95		95
PPL Energy Supply LLC [Member] | Recurring [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	6		9
PPL Energy Supply LLC [Member] | Recurring [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	77		82
PPL Energy Supply LLC [Member] | Recurring [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	38		40
PPL Energy Supply LLC [Member] | Recurring [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	5		3
PPL Energy Supply LLC [Member] | Recurring [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	1		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member]	'		'
Assets	'		'
Cash and cash equivalents	239		413
Restricted cash and cash equivalents	85	[1]	63	[1]
Price risk management assets:	'		'
Energy commodities assets	3		2
Total price risk management assets	3		2
NDT funds	550		437
Auction rate securities	'		'
Total assets	877		915
Price risk management liabilities:	'		'
Energy commodities liabilities	4		2
Total price risk management liabilities	4		2
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	14		11
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	409		308
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	33		25
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	95		95
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 1 [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	-1		-2
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Energy commodities assets	1,123		2,037
Total price risk management assets	1,123		2,037
NDT funds	314		275
Auction rate securities	'		3
Total assets	1,437		2,315
Price risk management liabilities:	'		'
Energy commodities liabilities	1,028		1,557
Total price risk management liabilities	1,028		1,557
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	138		104
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	48		35
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	6		9
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	77		82
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	38		40
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	5		3
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 2 [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	2		2
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Energy commodities assets	62		29
Total price risk management assets	62		29
NDT funds	'		'
Auction rate securities	16	[2]	13	[2]
Total assets	78		42
Price risk management liabilities:	'		'
Energy commodities liabilities	38		7
Total price risk management liabilities	38		7
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | Cash And Cash Equivalents [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | United States Large Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | United States Mid Small Cap Equity Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | US Treasury Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | US Government Sponsored Agency Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | Municipality Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | Investment Grade Corporate Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | Other Debt Securities [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Level 3 [Member] | Receivables Payables Net [Member]	'		'
Price risk management assets:	'		'
NDT funds	'		'
PPL Electric Utilities Corp [Member] | Recurring [Member]	'		'
Assets	'		'
Cash and cash equivalents	25		140
Restricted cash and cash equivalents	12	[3]	13	[3]
Price risk management assets:	'		'
Total assets	37		153
PPL Electric Utilities Corp [Member] | Recurring [Member] | Level 1 [Member]	'		'
Assets	'		'
Cash and cash equivalents	25		140
Restricted cash and cash equivalents	12	[3]	13	[3]
Price risk management assets:	'		'
Total assets	37		153
PPL Electric Utilities Corp [Member] | Recurring [Member] | Level 2 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Total assets	'		'
PPL Electric Utilities Corp [Member] | Recurring [Member] | Level 3 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Total assets	'		'
LG And E And KU Energy LLC [Member] | Recurring [Member]	'		'
Assets	'		'
Cash and cash equivalents	35		43
Restricted cash and cash equivalents	22	[4]	32	[4]
Price risk management assets:	'		'
Interest rate swaps assets	'		14
Total price risk management assets	'		14
Total assets	57		89
Price risk management liabilities:	'		'
Interest rate swaps liabilities	36		58
Total price risk management liabilities	36		58
LG And E And KU Energy LLC [Member] | Recurring [Member] | Level 1 [Member]	'		'
Assets	'		'
Cash and cash equivalents	35		43
Restricted cash and cash equivalents	22	[4]	32	[4]
Price risk management assets:	'		'
Interest rate swaps assets	'		'
Total price risk management assets	'		'
Total assets	57		75
Price risk management liabilities:	'		'
Interest rate swaps liabilities	'		'
Total price risk management liabilities	'		'
LG And E And KU Energy LLC [Member] | Recurring [Member] | Level 2 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Interest rate swaps assets	'		14
Total price risk management assets	'		14
Total assets	'		14
Price risk management liabilities:	'		'
Interest rate swaps liabilities	36		58
Total price risk management liabilities	36		58
LG And E And KU Energy LLC [Member] | Recurring [Member] | Level 3 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Interest rate swaps assets	'		'
Total price risk management assets	'		'
Total assets	'		'
Price risk management liabilities:	'		'
Interest rate swaps liabilities	'		'
Total price risk management liabilities	'		'
Louisville Gas And Electric Co [Member] | Recurring [Member]	'		'
Assets	'		'
Cash and cash equivalents	8		22
Restricted cash and cash equivalents	22	[4]	32	[4]
Price risk management assets:	'		'
Interest rate swaps assets	'		7
Total price risk management assets	'		7
Total assets	30		61
Price risk management liabilities:	'		'
Interest rate swaps liabilities	36		58
Total price risk management liabilities	36		58
Louisville Gas And Electric Co [Member] | Recurring [Member] | Level 1 [Member]	'		'
Assets	'		'
Cash and cash equivalents	8		22
Restricted cash and cash equivalents	22	[4]	32	[4]
Price risk management assets:	'		'
Interest rate swaps assets	'		'
Total price risk management assets	'		'
Total assets	30		54
Price risk management liabilities:	'		'
Interest rate swaps liabilities	'		'
Total price risk management liabilities	'		'
Louisville Gas And Electric Co [Member] | Recurring [Member] | Level 2 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Interest rate swaps assets	'		7
Total price risk management assets	'		7
Total assets	'		7
Price risk management liabilities:	'		'
Interest rate swaps liabilities	36		58
Total price risk management liabilities	36		58
Louisville Gas And Electric Co [Member] | Recurring [Member] | Level 3 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Restricted cash and cash equivalents	'		'
Price risk management assets:	'		'
Interest rate swaps assets	'		'
Total price risk management assets	'		'
Total assets	'		'
Price risk management liabilities:	'		'
Interest rate swaps liabilities	'		'
Total price risk management liabilities	'		'
Kentucky Utilities Co [Member] | Recurring [Member]	'		'
Assets	'		'
Cash and cash equivalents	21		21
Price risk management assets:	'		'
Interest rate swaps assets	'		7
Total price risk management assets	'		7
Total assets	21		28
Kentucky Utilities Co [Member] | Recurring [Member] | Level 1 [Member]	'		'
Assets	'		'
Cash and cash equivalents	21		21
Price risk management assets:	'		'
Interest rate swaps assets	'		'
Total price risk management assets	'		'
Total assets	21		21
Kentucky Utilities Co [Member] | Recurring [Member] | Level 2 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Price risk management assets:	'		'
Interest rate swaps assets	'		7
Total price risk management assets	'		7
Total assets	'		7
Kentucky Utilities Co [Member] | Recurring [Member] | Level 3 [Member]	'		'
Assets	'		'
Cash and cash equivalents	'		'
Price risk management assets:	'		'
Interest rate swaps assets	'		'
Total price risk management assets	'		'
Total assets	'		'
[1]	Current portion is included in "Restricted cash and cash equivalents" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
[2]	Included in "Other investments" on the Balance Sheets.
[3]	Current portion is included in "Other current assets" and the long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
[4]	Included in "Other noncurrent assets" on the Balance Sheets.

Fair_Value_Measurements_and_Cr4

Fair Value Measurements and Credit Concentration (Net Asset and Liability Measured on Recurring Basis Level 3 Unobservable Inputs Reconciliation Rollforward) (Details) (Level 3 [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	$39		$41
Total realized/unrealized gains (losses)	'		'
Included in earnings	-5		1
Included in OCI	1	[1]	2	[1]
Sales	-2		-5
Settlements	-3		-13
Transfers into Level 3	16		8
Transfers out of Level 3	-3		5
Balance at end of period	43		39
Energy Commodities, Net [Member]	'		'
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	22		13
Total realized/unrealized gains (losses)	'		'
Included in earnings	-5		2
Included in OCI	'		1	[1]
Sales	-2		'
Settlements	-3		-13
Transfers into Level 3	10		8
Transfers out of Level 3	2		11
Balance at end of period	24		22
Auction Rate Securities [Member]	'		'
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	16		24
Total realized/unrealized gains (losses)	'		'
Included in earnings	'		'
Included in OCI	'		'
Sales	'		-5
Settlements	'		'
Transfers into Level 3	3		'
Transfers out of Level 3	'		-3
Balance at end of period	19		16
Cross Currency Swaps [Member]	'		'
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	1		4
Total realized/unrealized gains (losses)	'		'
Included in earnings	'		-1
Included in OCI	1	[1]	1	[1]
Sales	'		'
Settlements	'		'
Transfers into Level 3	3		'
Transfers out of Level 3	-5		-3
Balance at end of period	'		1
PPL Energy Supply LLC [Member]	'		'
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	35		32
Total realized/unrealized gains (losses)	'		'
Included in earnings	-5		2
Included in OCI	'		1	[2]
Sales	-2		-3
Settlements	-3		-13
Transfers into Level 3	13		8
Transfers out of Level 3	2		8
Balance at end of period	40		35
PPL Energy Supply LLC [Member] | Energy Commodities, Net [Member]	'		'
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	22		13
Total realized/unrealized gains (losses)	'		'
Included in earnings	-5		2
Included in OCI	'		1	[2]
Sales	-2		'
Settlements	-3		-13
Transfers into Level 3	10		8
Transfers out of Level 3	2		11
Balance at end of period	24		22
PPL Energy Supply LLC [Member] | Auction Rate Securities [Member]	'		'
Reconciliation of net assets and liabilities	'		'
Balance at beginning of period	13		19
Total realized/unrealized gains (losses)	'		'
Included in earnings	'		'
Included in OCI	'		'
Sales	'		-3
Settlements	'		'
Transfers into Level 3	3		'
Transfers out of Level 3	'		-3
Balance at end of period	$16		$13
[1]	"Energy Commodities" and "Cross-Currency Swaps" are included in "Qualifying derivatives" and "Auction Rate Securities" are included in "Available-for-sale securities" on the Statements of Comprehensive Income.
[2]	"Energy Commodities" are included in "Qualifying derivatives" and "Auction Rate Securities" are included in "Available-for-sale securities" on the Statements of Comprehensive Income.

Fair_Value_Measurements_and_Cr5

Fair Value Measurements and Credit Concentration (Net Assets and Liabilities Measured on Recurring and Nonrecurring Basis Level 3 Significant Unobservable Inputs) (Details) (Level 3 [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	36	[1]	24	[1]
Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Observable wholesale prices used as proxy for retail delivery points	100.00%	[2]	100.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Observable wholesale prices used as proxy for retail delivery points	10.00%	[2]	21.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Observable wholesale prices used as proxy for retail delivery points	86.00%	[2]	75.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		-4	[3]
Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model used to calculate forward basis prices	'		24.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model used to calculate forward basis prices	'		24.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model used to calculate forward basis prices	'		24.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		2	[4]
Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Historical settled prices used to model forward prices	'		100.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Historical settled prices used to model forward prices	'		100.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Historical settled prices used to model forward prices	'		100.00%	[2]
Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	-12	[5]	'
Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model	100.00%	[5]	'
Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model	100.00%	[5]	'
Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model	100.00%	[5]	'
Recurring [Member] | Auction Rate Securities [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	19	[6]	16	[6]
Recurring [Member] | Auction Rate Securities [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Modeled from SIFMA Index	80.00%	[2]	74.00%	[2]
Recurring [Member] | Auction Rate Securities [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Modeled from SIFMA Index	10.00%	[2]	54.00%	[2]
Recurring [Member] | Auction Rate Securities [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Modeled from SIFMA Index	63.00%	[2]	64.00%	[2]
Recurring [Member] | Cross Currency Swaps [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		1	[7]
Recurring [Member] | Cross Currency Swaps [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Credit valuation adjustment	'		22.00%	[2]
Recurring [Member] | Cross Currency Swaps [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Credit valuation adjustment	'		22.00%	[2]
Recurring [Member] | Cross Currency Swaps [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Credit valuation adjustment	'		22.00%	[2]
Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		'
Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
Nonrecurring [Member] | Corette Plant And Emission Allowances [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		'
Nonrecurring [Member] | Corette Plant And Emission Allowances [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	100.00%		'
Nonrecurring [Member] | Corette Plant And Emission Allowances [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	100.00%		'
Nonrecurring [Member] | Corette Plant And Emission Allowances [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	100.00%		'
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	36	[1]	24	[1]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Observable wholesale prices used as proxy for retail delivery points	100.00%	[2]	100.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Observable wholesale prices used as proxy for retail delivery points	10.00%	[2]	21.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Retail Natural Gas Sales Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Observable wholesale prices used as proxy for retail delivery points	86.00%	[2]	75.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		-4	[3]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model used to calculate forward basis prices	'		24.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model used to calculate forward basis prices	'		24.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Power Sales Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model used to calculate forward basis prices	'		24.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		2	[4]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Historical settled prices used to model forward prices	'		100.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Historical settled prices used to model forward prices	'		100.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Financial Transmission Rights Purchase Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Historical settled prices used to model forward prices	'		100.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	-12	[5]	'
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model	100.00%	[5]	'
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model	100.00%	[5]	'
PPL Energy Supply LLC [Member] | Recurring [Member] | Energy Commodities, Net [Member] | Full Requirement Sales Contracts [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Proprietary model	100.00%	[5]	'
PPL Energy Supply LLC [Member] | Recurring [Member] | Auction Rate Securities [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	16	[6]	13	[6]
PPL Energy Supply LLC [Member] | Recurring [Member] | Auction Rate Securities [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Modeled from SIFMA Index	80.00%	[2]	74.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Auction Rate Securities [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Modeled from SIFMA Index	10.00%	[2]	57.00%	[2]
PPL Energy Supply LLC [Member] | Recurring [Member] | Auction Rate Securities [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Modeled from SIFMA Index	63.00%	[2]	65.00%	[2]
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Corette Plant And Emission Allowances [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		'
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Corette Plant And Emission Allowances [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	100.00%		'
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Corette Plant And Emission Allowances [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	100.00%		'
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Corette Plant And Emission Allowances [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	100.00%		'
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		'
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair value of net asset and (liability)	'		'
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Maximum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Minimum [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Equity Investment In Electric Energy Incorporated [Member] | Discounted Cash Flow [Member] | Weighted Average [Member]	'		'
Fair Value Inputs [Abstract]	'		'
Long term forward price curves and capital expenditure projections	'		100.00%
[1]	As the forward price of natural gas increases/(decreases), the fair value of contracts (decreases)/increases.
[2]	For energy commodities and auction rate securities, the range and weighted average represent the percentage of fair value derived from the unobservable inputs. For cross-currency swaps, the range and weighted average represent the percentage decrease in fair value due to the unobservable inputs used in the model to calculate the credit valuation adjustment.
[3]	As the forward price of basis increases/(decreases), the fair value of contracts (decreases)/increases.
[4]	As the forward implied spread increases/(decreases), the fair value of contracts increases/(decreases).
[5]	As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases. As the volumetric assumptions for full-requirement sales contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases). As the volumetric assumptions for full-requirement sales contracts in a loss position increase/(decrease), the fair value of contracts (decreases)/increases.
[6]	The model used to calculate fair value incorporates an assumption that the auctions will continue to fail. As the modeled forward rates of the SIFMA Index increase/(decrease), the fair value of the securities increases/(decreases).
[7]	The credit valuation adjustment incorporates projected probabilities of default and estimated recovery rates. As the credit valuation adjustment increases/(decreases), the fair value of the swaps (decreases)/increases.

Fair_Value_Measurements_and_Cr6

Fair Value Measurements and Credit Concentration (Net Asset and Liability Measured on Recurring Basis Level 3 Gain Loss Included in Earnings and Other Recurring Numeric Data) (Details) (Level 3 [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	($5)	$1
Energy Commodities, Net [Member] | Unregulated Wholesale Energy [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	-36	-19
Change in unrealized gains (losses) relating to positions still held at the reporting date	-23	-3
Energy Commodities, Net [Member] | Unregulated Retail Energy [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	25	26
Change in unrealized gains (losses) relating to positions still held at the reporting date	24	29
Energy Commodities, Net [Member] | Fuel [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	3	'
Change in unrealized gains (losses) relating to positions still held at the reporting date	'	'
Energy Commodities, Net [Member] | Energy Purchases [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	3	-5
Change in unrealized gains (losses) relating to positions still held at the reporting date	1	1
Cross Currency Swaps [Member] | Interest Expense [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	'	-1
Change in unrealized gains (losses) relating to positions still held at the reporting date	'	'
PPL Energy Supply LLC [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	-5	2
PPL Energy Supply LLC [Member] | Energy Commodities, Net [Member] | Unregulated Wholesale Energy [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	-36	-19
Change in unrealized gains (losses) relating to positions still held at the reporting date	-23	-3
PPL Energy Supply LLC [Member] | Energy Commodities, Net [Member] | Unregulated Retail Energy [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	25	26
Change in unrealized gains (losses) relating to positions still held at the reporting date	24	29
PPL Energy Supply LLC [Member] | Energy Commodities, Net [Member] | Fuel [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	3	'
Change in unrealized gains (losses) relating to positions still held at the reporting date	'	'
PPL Energy Supply LLC [Member] | Energy Commodities, Net [Member] | Energy Purchases [Member]	'	'
Net gains and losses on assets and liabilities [Abstract]	'	'
Total gains (losses) included in earnings	3	-5
Change in unrealized gains (losses) relating to positions still held at the reporting date	$1	$1

Fair_Value_Measurements_and_Cr7

Fair Value Measurements and Credit Concentration (Nonrecurring Fair Value Measurements and Credit Concentration) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Credit Concentration Associated with Financial Instruments (Numeric) [Abstract]	'		'		'
Gross credit exposure from energy trading partners	$1,000,000,000		'		'
Net credit exposure to energy trading partners	539,000,000		'		'
Dollar exposure to top ten energy trading counterparties	281,000,000		'		'
Percentage exposure to top ten energy trading counterparties	52.00%		'		'
Number of counterparties in top ten that have investment grade credit rating	9		'		'
Percentage of top ten's exposure that consists of counterparties with investment grade credit rating (in hundreths)	95.00%		'		'
Carrying Amount [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Contract adjustment payments	21,000,000	[1]	105,000,000	[1]	'
Long-term debt	20,907,000,000		19,476,000,000		'
Fair Value [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Contract adjustment payments	22,000,000		106,000,000		'
Long-term debt	22,177,000,000		21,671,000,000		'
Nonrecurring [Member] | Carrying Amount [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	65,000,000	[2]	'		'
Equity investment in EEI	'		25,000,000	[2]	'
RECs	'		'		6,000,000	[2],[3]
Nonrecurring [Member] | Level 2 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	'		'		'
Equity investment in EEI	'		'		'
RECs	'		'		1,000,000	[3]
Nonrecurring [Member] | Level 3 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	'		'		'
Equity investment in EEI	'		'		'
RECs	'		'		'
Nonrecurring [Member] | Loss [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	65,000,000	[4]	'		'
Equity investment in EEI	'		25,000,000	[4]	'
RECs	'		'		5,000,000	[3],[4]
PPL Energy Supply LLC [Member]	'		'		'
Credit Concentration Associated with Financial Instruments (Numeric) [Abstract]	'		'		'
Gross credit exposure from energy trading partners	1,000,000,000		'		'
Net credit exposure to energy trading partners	536,000,000		'		'
Dollar exposure to top ten energy trading counterparties	281,000,000		'		'
Percentage exposure to top ten energy trading counterparties	52.00%		'		'
Number of counterparties in top ten that have investment grade credit rating	9		'		'
Percentage of top ten's exposure that consists of counterparties with investment grade credit rating (in hundreths)	95.00%		'		'
PPL Energy Supply LLC [Member] | Carrying Amount [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	2,525,000,000		3,272,000,000		'
PPL Energy Supply LLC [Member] | Fair Value [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	2,658,000,000		3,556,000,000		'
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Carrying Amount [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	65,000,000	[2]	'		'
RECs	'		'		6,000,000	[2],[3]
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Level 2 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	'		'		'
RECs	'		'		1,000,000	[3]
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Level 3 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	'		'		'
RECs	'		'		'
PPL Energy Supply LLC [Member] | Nonrecurring [Member] | Loss [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Corette plant and emission allowances	65,000,000	[4]	'		'
RECs	'		'		5,000,000	[3],[4]
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	2,315,000,000		1,967,000,000		'
PPL Electric Utilities Corp [Member] | Fair Value [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	2,483,000,000		2,333,000,000		'
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	4,565,000,000		4,075,000,000		'
LG And E And KU Energy LLC [Member] | Fair Value [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	4,672,000,000		4,423,000,000		'
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Carrying Amount [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		25,000,000	[2]	'
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Level 2 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		'		'
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Level 3 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		'		'
LG And E And KU Energy LLC [Member] | Nonrecurring [Member] | Loss [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		25,000,000	[4]	'
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	1,353,000,000		1,112,000,000		'
Louisville Gas And Electric Co [Member] | Fair Value [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	1,372,000,000		1,178,000,000		'
Kentucky Utilities Co [Member] | Carrying Amount [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	2,091,000,000		1,842,000,000		'
Kentucky Utilities Co [Member] | Fair Value [Member]	'		'		'
Fair value of Financial Instruments Not Recorded at Fair Value - Other	'		'		'
Long-term debt	2,155,000,000		2,056,000,000		'
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Carrying Amount [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		25,000,000	[2]	'
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Level 2 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		'		'
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Level 3 [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		'		'
Kentucky Utilities Co [Member] | Nonrecurring [Member] | Loss [Member]	'		'		'
Nonrecurring Fair Value Measurements [Abstract]	'		'		'
Equity investment in EEI	'		$25,000,000	[4]	'
[1]	Included in "Other current liabilities" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
[2]	Represents carrying value before fair value measurement.
[3]	Current and long-term RECs are included in "Other current assets" and "Other intangibles" in their respective areas on the Balance Sheets.
[4]	The loss on the Corette plant and emission allowances was recorded in the Supply segment and included in "Other operation and maintenance" on the Statement of Income. The loss on the EEI investment was recorded in the Kentucky Regulated segment and included in "Other-Than-Temporary Impairments" on the Statement of Income. Losses on RECs were recorded in the Supply segment and included in "Other operation and maintenance" on the Statements of Income.

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities (Intro) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MW
Master Netting Arrangements (Numeric) [Line Items]	'	'	'
Cash collateral posted under master netting arrangements	$22	$32	'
Commodity Price Risk (Non-trading) [Line Items]	'	'	'
Baseload generation fleet capacity (in MW)	7,369	'	'
Intermediate and peaking generation fleet capacity (in MW)	3,309	'	'
Commodity Price Risk (Non-trading) - Cash Flow Hedges (Numeric) [Abstract]	'	'	'
Net unrealized after-tax gains (losses) expected to be reclassified into earnings within 12 months related to commodity price risk cash flow hedge contracts	25	'	'
No or insignificant amounts previously recorded in AOCI reclassified to earnings related to commodity price risk cash flow hedge contracts	'no reclassifications	'insignificant	'insignificant
No or immaterial hedge ineffectiveness related to commodity price risk cash flow hedge contracts	'insignificant	'insignificant	'
Hedge ineffectiveness after-tax gains (losses) related to commodity price risk cash flow hedge contracts	'	'	-22
Commodity Price Risk (Non-trading) - Economic Activity (Numeric) [Abstract]	'	'	'
Year of expiration of the maximum maturity date of economic activity derivative contracts	'2019	'	'
Fair value of commodity contracts classified as economic activity, net asset (liability)	107	346	'
Unregulated Retail Energy [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	12	-17	31
Unregulated Wholesale Energy [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	-721	-311	1,407
Fuel [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	-4	-14	6
Energy Purchases [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	586	442	-1,123
PPL Energy Supply LLC [Member]	'	'	'
Master Netting Arrangements (Numeric) [Line Items]	'	'	'
Obligation to return cash collateral obligation under master netting arrangement	9	112	'
Commodity Price Risk (Non-trading) [Line Items]	'	'	'
Baseload generation fleet capacity (in MW)	7,369	'	'
Intermediate and peaking generation fleet capacity (in MW)	3,309	'	'
Commodity Price Risk (Non-trading) - Cash Flow Hedges (Numeric) [Abstract]	'	'	'
Net unrealized after-tax gains (losses) expected to be reclassified into earnings within 12 months related to commodity price risk cash flow hedge contracts	25	'	'
No or insignificant amounts previously recorded in AOCI reclassified to earnings related to commodity price risk cash flow hedge contracts	'no reclassifications	'insignificant	'insignificant
No or immaterial hedge ineffectiveness related to commodity price risk cash flow hedge contracts	'insignificant	'insignificant	'
Hedge ineffectiveness after-tax gains (losses) related to commodity price risk cash flow hedge contracts	'	'	-22
Commodity Price Risk (Non-trading) - Economic Activity (Numeric) [Abstract]	'	'	'
Year of expiration of the maximum maturity date of economic activity derivative contracts	'2019	'	'
Fair value of commodity contracts classified as economic activity, net asset (liability)	107	346	'
PPL Energy Supply LLC [Member] | Unregulated Retail Energy [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	12	-17	31
PPL Energy Supply LLC [Member] | Unregulated Wholesale Energy [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	-721	-311	1,407
PPL Energy Supply LLC [Member] | Fuel [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	-4	-14	6
PPL Energy Supply LLC [Member] | Energy Purchases [Member]	'	'	'
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]	'	'	'
Pre-tax gain (loss)	586	442	-1,123
LG And E And KU Energy LLC [Member]	'	'	'
Master Netting Arrangements (Numeric) [Line Items]	'	'	'
Cash collateral posted under master netting arrangements	22	32	'
Louisville Gas And Electric Co [Member]	'	'	'
Master Netting Arrangements (Numeric) [Line Items]	'	'	'
Cash collateral posted under master netting arrangements	$22	$32	'

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities (Commodity Volumes Volumetric Activity) (Details)	Dec. 31, 2013
	MWh
Purchase Contracts [Member] | Power [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	4,348,927	[1]
Purchase Contracts [Member] | Power [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	18,931,370	[1]
Purchase Contracts [Member] | Capacity [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	501	[1]
Purchase Contracts [Member] | Capacity [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	9	[1]
Purchase Contracts [Member] | Gas [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	25,869,617	[1]
Purchase Contracts [Member] | Gas [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	19,082,945	[1]
Purchase Contracts [Member] | Coal [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	495,900	[1]
Purchase Contracts [Member] | Coal [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
Purchase Contracts [Member] | Coal [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
Purchase Contracts [Member] | Coal [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
Purchase Contracts [Member] | Financial Transmission Rights [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	9,581	[1]
Purchase Contracts [Member] | Financial Transmission Rights [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	1,705	[1]
Purchase Contracts [Member] | Financial Transmission Rights [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
Purchase Contracts [Member] | Financial Transmission Rights [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
Purchase Contracts [Member] | Oil [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	150,000	[1]
Purchase Contracts [Member] | Oil [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	380,869	[1]
Purchase Contracts [Member] | Oil [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	274,137	[1]
Purchase Contracts [Member] | Oil [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	101,261	[1]
Sales Contracts [Member] | Power [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	33,278,963	[1]
Sales Contracts [Member] | Power [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	14,421,817	[1]
Sales Contracts [Member] | Capacity [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	19,575	[1]
Sales Contracts [Member] | Capacity [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	3,929	[1]
Sales Contracts [Member] | Gas [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	33,082,289	[1]
Sales Contracts [Member] | Gas [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	9,202,403	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Power [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	4,348,927	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Power [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	18,931,370	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Capacity [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	501	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Capacity [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	9	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Gas [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	25,869,617	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Gas [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	19,082,945	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Coal [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	495,900	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Coal [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Coal [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Coal [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Financial Transmission Rights [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	9,581	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Financial Transmission Rights [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	1,705	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Financial Transmission Rights [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Financial Transmission Rights [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	'
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Oil [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	150,000	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Oil [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	380,869	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Oil [Member] | 2016 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	274,137	[1]
PPL Energy Supply LLC [Member] | Purchase Contracts [Member] | Oil [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	101,261	[1]
PPL Energy Supply LLC [Member] | Sales Contracts [Member] | Power [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	33,278,963	[1]
PPL Energy Supply LLC [Member] | Sales Contracts [Member] | Power [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	14,421,817	[1]
PPL Energy Supply LLC [Member] | Sales Contracts [Member] | Capacity [Member] | 2014 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	19,575	[1]
PPL Energy Supply LLC [Member] | Sales Contracts [Member] | Capacity [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	3,929	[1]
PPL Energy Supply LLC [Member] | Sales Contracts [Member] | Gas [Member] | 2015 [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	33,082,289	[1]
PPL Energy Supply LLC [Member] | Sales Contracts [Member] | Gas [Member] | Thereafter [Member]	'
Commodity Volumetric Activity [Line Items]	'
Notional amount (in units)	9,202,403	[1]
[1]	Volumes for option contracts factor in the probability of an option being exercised and may be less than the notional amount of the option.

Derivative_Instruments_and_Hed5

Derivative Instruments and Hedging Activities (Risk Disclosures) (Details)

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

Jun. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Cash Flow Hedges [Member]

Cash Flow Hedges [Member]

Cash Flow Hedges [Member]

Cash Flow Hedges [Member]

Cash Flow Hedges [Member]

Cash Flow Hedges [Member]

Fair Value Hedges [Member]

Fair Value Hedges [Member]

Fair Value Hedges [Member]

Fair Value Hedges [Member]

Economic Hedges [Member]

Economic Hedges [Member]

Economic Hedges [Member]

Economic Hedges [Member]

Net Investment Hedges [Member]

Net Investment Hedges [Member]

Net Investment Hedges [Member]

Net Investment Hedges [Member]

Net Investment Hedges [Member]

KU [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

USD ($)

USD ($)

USD ($)

Interest Rate Swap Contracts [Member]

Cross Currency Interest Rate Swaps [Member]

USD ($)

USD ($)

Interest Rate Swap Contracts [Member]

Foreign Currency Contracts [Member]

Foreign Currency Contracts [Member]

Foreign Currency Contracts [Member]

Foreign Currency Contracts [Member]

Foreign Currency Contracts [Member]

Foreign Currency Contracts [Member]

Intercompany Loans [Member]

Intercompany Loans [Member]

Cash Flow Hedges [Member]

USD ($)

USD ($)

USD ($)

Cash Flow Hedges [Member]

Economic Hedges [Member]

USD ($)

USD ($)

USD ($)

Cash Flow Hedges [Member]

Economic Hedges [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

GBP (£)

USD ($)

USD ($)

GBP (£)

USD ($)

USD ($)

GBP (£)

Interest Rate Swap Contracts [Member]

Interest Rate Swap Contracts [Member]

Interest Rate Swap Contracts [Member]

Interest Rate Swap Contracts [Member]

Interest Rate Swap Contracts [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Interest Rate Risk and Foreign Currency Risk [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notional amount

'

'

'

'

$1,300,000,000

$1,300,000,000

$99,000,000

'

'

'

$179,000,000

'

'

'

$477,000,000

£ 301,000,000

'

'

'

'

'

'

'

'

$179,000,000

'

'

'

'

$179,000,000

'

'

'

Notional amount of nonderivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

69,000,000

42,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Year of expiration of the maximum maturity date of interest rate cash flow hedge contracts

'

'

'

'

'2044

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Latest maturity date of cross-currency cash flow hedge contracts

'

'

'

'

'

'2028

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Insignificant or no hedge ineffectiveness associated with interest rate cash flow hedges

'

'insignificant

'insignificant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Hedge ineffectiveness associated with interest rate cash flow hedges

-4,000,000

'

'

-9,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

No or insignificant after-tax gains (losses) previously recorded in AOCI reclassified to earnings related to interest rate cash flow hedge contracts

'

'no such reclassifications

'no such reclassifications

'no such reclassifications

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net unrealized after-tax gains (losses) on interest rate cash flow hedge contracts expected to be reclassified into earnings during next 12 months

'

-10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal amount of debt related to interest rate swap that is receiving regulatory accounting treatment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000,000

'

'

'

500,000,000

'

'

'

'

250,000,000

'

'

'

'

Cash settlement on terminated swaps

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

86,000,000

'

'

'

'

43,000,000

'

'

'

'

43,000,000

'

'

Interest Rate Risk - Fair Value Hedges (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Year of expiration of the maximum maturity date of interest rate fair value hedge contracts

'

'

'

'

'

'

'2047

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

No or insignificant hedge ineffectiveness associated with interest rate fair value hedges

'

'

'

'

'

'

'

'did not recognize

'did not recognize

'did not recognize

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

No or insignificant gains (losses) associated with interest rate fair value hedges being excluded from the assessment of hedge effectiveness

'

'

'

'

'

'

'

'did not recognize

'did not recognize

'did not recognize

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

No or insignificant gain (loss) associated with interest rate fair value hedges of debt issuances that no longer qualified as interest rate fair value hedges

'

'

'

'

'

'

'

'did not recognize

'did not recognize

'did not recognize

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal amount of debt related to discontinuance of fair value hedge

'

'

'

'

'

'

'

'

'

400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) resulting from firm commitments no longer qualifying as interest rate fair value hedges, pre-tax

'

'

'

'

'

'

'

'

'

22,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) resulting from firm commitments that no longer qualified as interest rate fair value hedges, after-tax

'

'

'

'

'

'

'

'

'

14,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Rate Risk - Economic Activity (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Year of expiration of the maximum maturity date of interest rate economic activity contracts

'

'

'

'

'

'

'

'

'

'

'2033

'

'

'

'

'

'

'

'

'

'

'

'

'

'2033

'

'

'

'

'2033

'

'

'

Foreign Currency Risk - Net Investment Hedges (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earliest settlement date of net investment hedge contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'May 2014

'May 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Latest settlement date of net investment hedge contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'December 2015

'December 2015

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Insignificant or no net after tax gains (losses) on net investment hedges recognized in the foreign currency translation adjustment component of AOCI

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'insignificant

'insignificant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net after tax gains (losses) on net investment hedges included in the foreign currency translation adjustment component of AOCI

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Foreign Currency Risk - Economic Activity (Numeric) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total exposure hedged related to foreign currency contracts for anticipated earnings hedges classified as economic activity

'

'

'

'

'

'

'

'

'

'

'

2,300,000,000

1,400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earliest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity

'

'

'

'

'

'

'

'

'

'

'

'January 2014

'January 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Latest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity

'

'

'

'

'

'

'

'

'

'

'

'December 2015

'December 2015

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gains (losses) on foreign currency contracts related to debt or commitments hedged with foreign currency contracts classified as economic activity

'

'

'

'

'

'

'

'

'

'

'

'

'

$55,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative_Instruments_and_Hed6

Derivative Instruments and Hedging Activities (Fair Values) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	$1,279		$2,097
Liability value	1,244		1,694
Derivatives Designated As Hedging Instruments [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	91	[1]	115	[1]
Liability value	52	[1]	28	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	82	[1]	73	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	82	[1],[2]	14	[1],[2]
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		59	[1]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	9	[1]	42	[1]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	9	[1],[2]	1	[1],[2]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		14	[1]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		27	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	20	[1]	27	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		22	[1],[2]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	4	[1]	3	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	16	[1]	2	[1]
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	32	[1]	1	[1]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	28	[1]	1	[1]
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	4	[1]	'
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
Derivatives Not Designated As Hedging Instruments [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	1,188	[1]	1,982	[1]
Liability value	1,192	[1]	1,666	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	860	[1]	1,452	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	860	[1]	1,452	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	328	[1]	530	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	328	[1]	530	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	809	[1]	1,038	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	4	[1],[2]	5	[1],[2]
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	55	[1]	23	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	750	[1]	1,010	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	383	[1]	628	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	32	[1],[2]	53	[1],[2]
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	31	[1]	19	[1]
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	320	[1]	556	[1]
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		86	[1]
Liability value	'		'
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		59	[1]
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		59	[1]
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		27	[1]
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		27	[1]
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
PPL Energy Supply LLC [Member] | Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	'		'
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	1,188	[1]	1,982	[1]
Liability value	1,070	[1]	1,566	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	860	[1]	1,452	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	860	[1]	1,452	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	328	[1]	530	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	328	[1]	530	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	750	[1]	1,010	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	750	[1]	1,010	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	320	[1]	556	[1]
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Commodity Contracts [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	320	[1]	556	[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	'		14	[1]
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	'		'
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Asset value	'		'
Liability value	36	[1]	58	[1]
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	'		'
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	'		'
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	'		'
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	'		'
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	4	[1]	5	[1]
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	4	[1]	5	[1]
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	32	[1]	53	[1]
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	32	[1]	53	[1]
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	'		7	[1]
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	'		'
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	'		'
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	'		'
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]	'		'
Fair Values by Balance Sheet Location [Abstract]	'		'
Liability value	4	[1]	5	[1]
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]	'		'
Asset value	'		'
Liability value	32	[1]	53	[1]
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		7	[1]
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	'		'
[1]	Represents the location on the Balance Sheets (b)        Excludes accrued interest, if applicable.
[2]	Excludes accrued interest, if applicable

Derivative_Instruments_and_Hed7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value Hedges [Member] | Interest Rate Swaps [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Hedged items in fair value hedging relationships	'	'Fixed rate debt	'Fixed rate debt
Fair Value 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	'	'	$2
Gain (loss) recognized in income on related item	'	3	25
Fair Value Hedges [Member] | Interest Rate Swaps [Member] | Other Income (Expense) Net [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	'	'	'
Gain (loss) recognized in income on related item	'	'	22
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)	163	712	616
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	1	-3	-51
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)	86	71	341
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	72	14	'
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)	127	-28	-55
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)	-20	-18	-13
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	-13
Cash Flow Hedges [Member] | Interest Rate 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)	'	1	'
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in OCI on derivative (effective portion)	-41	-15	-35
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	1	-2	5
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
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)	-28	-23	29
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
Cash Flow Hedges [Member] | Commodity 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)	'	114	431
Cash Flow Hedges [Member] | Commodity Contracts [Member] | Wholesale Energy Marketing [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	263	891	835
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	1	-1	-39
Cash Flow Hedges [Member] | Commodity Contracts [Member] | Fuel [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	'	'	1
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
Cash Flow Hedges [Member] | Commodity Contracts [Member] | Depreciation [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	2	2	2
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
Cash Flow Hedges [Member] | Commodity Contracts [Member] | Energy Purchases [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	-58	-139	-243
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	-2	1
Cash Flow Hedges [Member] | Commodity Contracts [Member] | Other Operation And Maintenance [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in OCI on derivative (effective portion)	3	'	'
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
Derivatives Not Designated As Hedging Instruments [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	26	204	201
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	22	1	-26
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] | Commodity Contracts [Member] | Wholesale Energy Marketing [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	-85	1,199	1,600
Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Fuel [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	2	'	-1
Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Energy Purchases [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	130	-965	-1,493
Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Unregulated Retail Electric And Gas [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	25	30	39
Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Utility [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	'	'	-1
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	-38	-52	65
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)	-14	-7	6
PPL Energy Supply LLC [Member] | Fair Value Hedges [Member] | Interest Rate Swaps [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Hedged items in fair value hedging relationships	'	'	'Fixed rate debt
PPL Energy Supply LLC [Member] | Fair Value 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	'	'	'
Gain (loss) recognized in income on related item	'	'	2
PPL Energy Supply LLC [Member] | Cash Flow Hedges [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in OCI on derivative (effective portion)	'	114	431
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	207	754	595
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	1	-3	-38
PPL Energy Supply LLC [Member] | Cash Flow Hedges [Member] | Commodity Contracts [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in OCI on derivative (effective portion)	'	114	431
PPL Energy Supply LLC [Member] | Cash Flow Hedges [Member] | Commodity Contracts [Member] | Wholesale Energy Marketing [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	263	891	835
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	1	-1	-39
PPL Energy Supply LLC [Member] | Cash Flow Hedges [Member] | Commodity Contracts [Member] | Fuel [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	'	'	1
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
PPL Energy Supply LLC [Member] | Cash Flow Hedges [Member] | Commodity Contracts [Member] | Depreciation [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	2	2	2
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	'	'
PPL Energy Supply LLC [Member] | Cash Flow Hedges [Member] | Commodity Contracts [Member] | Energy Purchases [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) reclassified from AOCI into income on derivative (effective portion)	-58	-139	-243
Gain (loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	'	-2	1
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	72	264	145
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Wholesale Energy Marketing [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	-85	1,199	1,600
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Fuel [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	2	'	-1
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Energy Purchases [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	130	-965	-1,493
PPL Energy Supply LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Unregulated Retail Electric And Gas [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	25	30	39
LG And E And KU Energy LLC [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	72	14	'
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	-8	-8	-9
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized as regulatory liabilities/assets	22	1	-26
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	-8	-8	-8
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Operating Revenues [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	'	'	-1
Louisville Gas And Electric Co [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	36	7	'
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	-8	-8	-9
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized as regulatory liabilities/assets	22	1	-26
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	-8	-8	-8
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Commodity Contracts [Member] | Operating Revenues [Member]	'	'	'
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]	'	'	'
Gain (loss) recognized in income on derivative	'	'	-1
Kentucky Utilities Co [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	$36	$7	'

Derivative_Instruments_and_Hed8

Derivative Instruments and Hedging Activities (Offseting Derivative Instruments and Credit Risk-Related Features) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	$1,279		$2,097
Derivative instruments eligible for offset - assets	973		1,432
Net assets	299		554
Gross liabilities	1,244		1,694
Derivative instruments eligible for offset - liabilities	973		1,432
Cash collateral pledged eligible for offset - liabilities	24		39
Net liabilities	247		223
Credit Risk-Related Contingent Features [Abstract]	'		'
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	245		'
Aggregate fair value of collateral posted on these derivative instruments	41		'
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	214	[1]	'
Energy Commodities [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	1,188		2,068
Derivative instruments eligible for offset - assets	912		1,413
Cash collateral received eligible for offset - assets	7		111
Net assets	269		544
Gross liabilities	1,070		1,566
Derivative instruments eligible for offset - liabilities	912		1,413
Cash collateral pledged eligible for offset - liabilities	1		9
Net liabilities	157		144
Treasury Derivatives [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	91		29
Derivative instruments eligible for offset - assets	61		19
Cash collateral received eligible for offset - assets	'		'
Net assets	30		10
Gross liabilities	174		128
Derivative instruments eligible for offset - liabilities	61		19
Cash collateral pledged eligible for offset - liabilities	23		30
Net liabilities	90		79
PPL Energy Supply LLC [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Cash collateral received eligible for offset - assets	9		112
Credit Risk-Related Contingent Features [Abstract]	'		'
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	157		'
Aggregate fair value of collateral posted on these derivative instruments	19		'
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	147	[1]	'
PPL Energy Supply LLC [Member] | Energy Commodities [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	1,188		2,068
Derivative instruments eligible for offset - assets	912		1,413
Cash collateral received eligible for offset - assets	7		111
Net assets	269		544
Gross liabilities	1,070		1,566
Derivative instruments eligible for offset - liabilities	912		1,413
Cash collateral pledged eligible for offset - liabilities	1		9
Net liabilities	157		144
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	26		'
Aggregate fair value of collateral posted on these derivative instruments	22		'
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	6	[1]	'
LG And E And KU Energy LLC [Member] | Treasury Derivatives [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	'		14
Derivative instruments eligible for offset - assets	'		'
Cash collateral received eligible for offset - assets	'		'
Net assets	'		14
Gross liabilities	36		58
Derivative instruments eligible for offset - liabilities	'		'
Cash collateral pledged eligible for offset - liabilities	20		30
Net liabilities	16		28
Louisville Gas And Electric Co [Member]	'		'
Credit Risk-Related Contingent Features [Abstract]	'		'
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	26		'
Aggregate fair value of collateral posted on these derivative instruments	22		'
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	6	[1]	'
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	'		7
Derivative instruments eligible for offset - assets	'		'
Cash collateral received eligible for offset - assets	'		'
Net assets	'		7
Gross liabilities	36		58
Derivative instruments eligible for offset - liabilities	'		'
Cash collateral pledged eligible for offset - liabilities	20		30
Net liabilities	16		28
Kentucky Utilities Co [Member] | Treasury Derivatives [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Gross assets	'		7
Derivative instruments eligible for offset - assets	'		'
Cash collateral received eligible for offset - assets	'		'
Net assets	'		7
Gross liabilities	'		'
Derivative instruments eligible for offset - liabilities	'		'
Cash collateral pledged eligible for offset - liabilities	'		'
Net liabilities	'		'
[1]	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Goodwill_and_Other_Intangible_2

Goodwill and Other Intangible Assets (Goodwill) (Details) (USD $)

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Kentucky Regulated [Member]

Kentucky Regulated [Member]

Kentucky Regulated [Member]

United Kingdom Regulated [Member]

United Kingdom Regulated [Member]

Supply [Member]

Supply [Member]

Supply [Member]

PPL Energy Supply LLC [Member]

PPL Energy Supply LLC [Member]

LG And E And KU Energy LLC [Member]

LG And E And KU Energy LLC [Member]

Louisville Gas And Electric Co [Member]

Louisville Gas And Electric Co [Member]

Kentucky Utilities Co [Member]

Kentucky Utilities Co [Member]

Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period

$4,158

$4,114

[1]

$662

[1]

$662

[1]

$662

[1]

$3,076

[1]

$3,032

[1]

$420

[1]

$420

[1]

$420

[1]

$86

$86

$996

$996

$389

$389

$607

$607

Changes during the period

67

[2]

44

[2]

'

'

'

67

[2]

44

[2]

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period

$4,225

$4,158

$662

[1]

$662

[1]

$662

[1]

$3,143

[1]

$3,076

[1]

$420

[1]

$420

[1]

$420

[1]

$86

$86

$996

$996

$389

$389

$607

$607

[1]

There were no accumulated impairment losses related to goodwill.

[2]

Primarily the effect of foreign currency exchange rates.

Goodwill_and_Other_Intangible_3

Goodwill and Other Intangible Assets (Other Intangibles) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	$1,060		$996		'
Finite-Lived Intangible Assets, Accumulated Amortization	364		302		'
Not subject to amortization due to indefinite life: [Line Items]	'		'		'
Gross carrying amount	255		238		'
Gross carrying amount - other intangible assets	1,315		1,234		'
Land And Transmission Rights [Member]	'		'		'
Not subject to amortization due to indefinite life: [Line Items]	'		'		'
Gross carrying amount	16		18		'
Easements [Member]	'		'		'
Not subject to amortization due to indefinite life: [Line Items]	'		'		'
Gross carrying amount	239	[1]	220	[1]	'
Contracts [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	408	[2]	408	[2]	'
Finite-Lived Intangible Assets, Accumulated Amortization	202		150		'
Land And Transmission Rights [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	331		284		'
Finite-Lived Intangible Assets, Accumulated Amortization	117		113		'
Emission Allowances And Renewable Energy Credits [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	16	[3]	17	[3]	'
Finite-Lived Intangible Assets, Accumulated Amortization	'		'		'
Amortization expense	23		12		16
Licenses And Other [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	305	[4]	287	[4]	'
Finite-Lived Intangible Assets, Accumulated Amortization	45	[4]	39	[4]	'
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	61		61		112
Forecasted amortization in 2014	58		'		'
Forecasted amortization in 2015	60		'		'
Forecasted amortization in 2016	35		'		'
Forecasted amortization in 2017	17		'		'
Forecasted amortization in 2018	17		'		'
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With Regulatory Offset [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	51		47		87
Forecasted amortization in 2014	48		'		'
Forecasted amortization in 2015	50		'		'
Forecasted amortization in 2016	27		'		'
Forecasted amortization in 2017	9		'		'
Forecasted amortization in 2018	9		'		'
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With No Regulatory Offset [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	10		14		25
Forecasted amortization in 2014	10		'		'
Forecasted amortization in 2015	10		'		'
Forecasted amortization in 2016	8		'		'
Forecasted amortization in 2017	8		'		'
Forecasted amortization in 2018	8		'		'
PPL Energy Supply LLC [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	323		307		'
Finite-Lived Intangible Assets, Accumulated Amortization	53		48		'
PPL Energy Supply LLC [Member] | Land And Transmission Rights [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	17		17		'
Finite-Lived Intangible Assets, Accumulated Amortization	14		13		'
PPL Energy Supply LLC [Member] | Emission Allowances And Renewable Energy Credits [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	11	[3]	13	[3]	'
Finite-Lived Intangible Assets, Accumulated Amortization	'		'		'
Amortization expense	23		12		16
PPL Energy Supply LLC [Member] | Licenses And Other [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	295	[4]	277	[4]	'
Finite-Lived Intangible Assets, Accumulated Amortization	39	[4]	35	[4]	'
PPL Energy Supply LLC [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	5		9		20
PPL Electric Utilities Corp [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	298		253		'
Finite-Lived Intangible Assets, Accumulated Amortization	103		100		'
Not subject to amortization due to indefinite life: [Line Items]	'		'		'
Gross carrying amount - other intangible assets	314		271		'
PPL Electric Utilities Corp [Member] | Land And Transmission Rights [Member]	'		'		'
Not subject to amortization due to indefinite life: [Line Items]	'		'		'
Gross carrying amount	16		18		'
PPL Electric Utilities Corp [Member] | Land And Transmission Rights [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	293		249		'
Finite-Lived Intangible Assets, Accumulated Amortization	102		99		'
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	5		4		'
Finite-Lived Intangible Assets, Accumulated Amortization	1		1		'
LG And E And KU Energy LLC [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	419		417		'
Finite-Lived Intangible Assets, Accumulated Amortization	198		146		'
LG And E And KU Energy LLC [Member] | Coal Contracts [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	269	[5]	269	[5]	'
Finite-Lived Intangible Assets, Accumulated Amortization	171	[5]	128	[5]	'
LG And E And KU Energy LLC [Member] | Land And Transmission Rights [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	20		18		'
Finite-Lived Intangible Assets, Accumulated Amortization	2		1		'
LG And E And KU Energy LLC [Member] | Emission Allowances [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	4	[6]	4	[6]	'
Finite-Lived Intangible Assets, Accumulated Amortization	'		'		'
LG And E And KU Energy LLC [Member] | Ohio Valley Electric Corporation Power Purchase Agreement [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	126	[7]	126	[7]	'
Finite-Lived Intangible Assets, Accumulated Amortization	25		17		'
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	52		47		88
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		87
Forecasted amortization in 2014	48		'		'
Forecasted amortization in 2015	50		'		'
Forecasted amortization in 2016	27		'		'
Forecasted amortization in 2017	9		'		'
Forecasted amortization in 2018	9		'		'
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	1		'		1
Louisville Gas And Electric Co [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	219		220		'
Finite-Lived Intangible Assets, Accumulated Amortization	99		76		'
Louisville Gas And Electric Co [Member] | Coal Contracts [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	124	[5]	124	[5]	'
Finite-Lived Intangible Assets, Accumulated Amortization	81	[5]	62	[5]	'
Louisville Gas And Electric Co [Member] | Land And Transmission Rights [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	7		8		'
Finite-Lived Intangible Assets, Accumulated Amortization	1		1		'
Louisville Gas And Electric Co [Member] | Emission Allowances [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	1	[6]	1	[6]	'
Finite-Lived Intangible Assets, Accumulated Amortization	'		'		'
Louisville Gas And Electric Co [Member] | Ohio Valley Electric Corporation Power Purchase Agreement [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	87	[7]	87	[7]	'
Finite-Lived Intangible Assets, Accumulated Amortization	17		13		'
Louisville Gas And Electric Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	23		23		46
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	23		23		45
Forecasted amortization in 2014	23		'		'
Forecasted amortization in 2015	24		'		'
Forecasted amortization in 2016	13		'		'
Forecasted amortization in 2017	6		'		'
Forecasted amortization in 2018	6		'		'
Louisville Gas And Electric Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With No Regulatory Offset [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	'		'		1
Kentucky Utilities Co [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	200		197		'
Finite-Lived Intangible Assets, Accumulated Amortization	99		70		'
Kentucky Utilities Co [Member] | Coal Contracts [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	145	[5]	145	[5]	'
Finite-Lived Intangible Assets, Accumulated Amortization	90	[5]	66	[5]	'
Kentucky Utilities Co [Member] | Land And Transmission Rights [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	13		10		'
Finite-Lived Intangible Assets, Accumulated Amortization	1		'		'
Kentucky Utilities Co [Member] | Emission Allowances [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	3	[6]	3	[6]	'
Finite-Lived Intangible Assets, Accumulated Amortization	'		'		'
Kentucky Utilities Co [Member] | Ohio Valley Electric Corporation Power Purchase Agreement [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Gross carrying amount	39	[7]	39	[7]	'
Finite-Lived Intangible Assets, Accumulated Amortization	8		4		'
Kentucky Utilities Co [Member] | Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits With Regulatory Offset [Member]	'		'		'
Subject to amortization: [Abstract]	'		'		'
Amortization expense	28		24		42
Forecasted amortization in 2014	24		'		'
Forecasted amortization in 2015	26		'		'
Forecasted amortization in 2016	13		'		'
Forecasted amortization in 2017	3		'		'
Forecasted amortization in 2018	3		'		'
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	$1		'		'
[1]	Gross carrying amount includes $88 million, which represents the fair value at the acquisition date of easements recognized as a result of the 2011 acquisition of WPD Midlands. See Note 10 for additional information.
[2]	Gross carrying amount includes the fair value at the acquisition date of coal contracts with terms favorable to market recognized as a result of the 2010 acquisition of LKE 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. 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]	"Other" includes costs for the development of licenses, the most significant of which is the COLA. Amortization of these costs begins when the related asset is placed in service. See Note 8 for additional information on the COLA.
[5]	Gross carrying amount represents 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.
[6]	Represents the fair value at the acquisition date of emission allowances recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability is recorded related to these emission allowances, which is being amortized as the emission allowances are consumed, eliminating any income statement impact. Consumption related to these emission allowances was insignificant in 2013 and in 2012.
[7]	Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. See Note 6 for additional information.

Goodwill_and_Other_Intangible_4

Goodwill and Other Intangible Assets (Other Intangibles-Aquired) (Details) (WPD Midlands [Member], Easements [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
WPD Midlands [Member] | Easements [Member]	'	'
Acquired indefinite-lived intangible assets: [Line Items]	'	'
Gross carrying amount	$88	$88

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Susquehanna Nuclear Plant ARO (Numeric) [Abstract]	'	'
Susquehanna accrued nuclear decommissioning obligation	$342	$316
Susquehanna NDT funds	864	712
Asset Retirement Obligation [Rollforward]	'	'
Balance at Beginning of Period	552	497
Accretion expense	38	36
Obligations incurred	6	9
Changes in estimated cash flow or settlement date	123	31
Effect of foreign currency exchange rates	1	1
Obligations settled	-15	-22
Balance at End of Period	705	552
PPL Energy Supply LLC [Member]	'	'
Susquehanna Nuclear Plant ARO (Numeric) [Abstract]	'	'
Susquehanna accrued nuclear decommissioning obligation	342	316
Susquehanna NDT funds	864	712
Asset Retirement Obligation [Rollforward]	'	'
Balance at Beginning of Period	375	359
Accretion expense	29	28
Obligations incurred	6	3
Changes in estimated cash flow or settlement date	1	-7
Obligations settled	-7	-8
Balance at End of Period	404	375
LG And E And KU Energy LLC [Member]	'	'
Asset Retirement Obligation [Rollforward]	'	'
Balance at Beginning of Period	131	118
Accretion expense	7	6
Obligations incurred	'	6
Changes in estimated cash flow or settlement date	122	15
Obligations settled	-8	-14
Balance at End of Period	252	131
Louisville Gas And Electric Co [Member]	'	'
Asset Retirement Obligation [Rollforward]	'	'
Balance at Beginning of Period	62	57
Accretion expense	3	3
Changes in estimated cash flow or settlement date	17	5
Obligations settled	-8	-3
Balance at End of Period	74	62
Kentucky Utilities Co [Member]	'	'
Asset Retirement Obligation [Rollforward]	'	'
Balance at Beginning of Period	69	61
Accretion expense	4	3
Obligations incurred	'	6
Changes in estimated cash flow or settlement date	105	10
Obligations settled	'	-11
Balance at End of Period	$178	$69

Variable_Interest_Entities_Det

Variable Interest Entities (Details) (Lower Mount Bethel Energy, LLC [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Variable Interest Entities [Line Items]	'	'	'
Original acquisition cost of the facility owned by a VIE	$455	'	'
Residual value guarantee percentage associated with VIE lease	70.52%	'	'
Debt associated with a VIE	'	437	'
Non-controlling interests associated with VIE	'	18	'
Additional depreciation expense for leasehold improvements associated with VIE	12	16	16
Amount paid during the period to purchase the Lower Mount Bethel plant, a consolidated Variable Interest Entity	455	'	'
Portion of purchase price paid to retire associated debt of the consolidated Variable Interest Entity	437	'	'
Portion of purchase price paid to make distribution to non controlling interest associated with the consolidated Variable Interest Entity	18	'	'
PPL Energy Supply LLC [Member]	'	'	'
Variable Interest Entities [Line Items]	'	'	'
Original acquisition cost of the facility owned by a VIE	455	'	'
Residual value guarantee percentage associated with VIE lease	70.52%	'	'
Debt associated with a VIE	'	437	'
Non-controlling interests associated with VIE	'	18	'
Additional depreciation expense for leasehold improvements associated with VIE	12	16	16
Amount paid during the period to purchase the Lower Mount Bethel plant, a consolidated Variable Interest Entity	455	'	'
Portion of purchase price paid to retire associated debt of the consolidated Variable Interest Entity	437	'	'
Portion of purchase price paid to make distribution to non controlling interest associated with the consolidated Variable Interest Entity	$18	'	'

AvailableforSale_Securities_De

Available-for-Sale Securities (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Available-for-Sale Securities Scheduled Maturity Dates of Debt Securities (Details) [Abstract]	'		'		'		'
Amortized cost - maturity less than 1 year	$7		'		'		'
Amortized cost - maturity between 1 and 5 years	97		'		'		'
Amortized cost - maturity between 6 and 10 years	54		'		'		'
Amortized cost - maturity in excess of 10 years	79		'		'		'
Amortized cost total	237		'		'		'
Fair value - maturity less than 1 year	7		'		'		'
Fair value - maturity between 1 and 5 years	99		'		'		'
Fair value - maturity between 6 and 10 years	55		'		'		'
Fair value - maturity in excess of 10 years	79		'		'		'
Fair value total	240		'		'		'
Available-for-Sale Securities Proceeds From and Realized Gains and Losses (Details) [Abstract]	'		'		'		'
Proceeds from sales of NDT securities	144		139		156		'
Other proceeds from sales	'		5		163		'
Gross realized gains	17	[1]	29	[1]	28	[1]	'
Gross realized losses	7	[1]	21	[1]	16	[1]	'
Short Term Investments (Numeric) [Abstract]	'		'		'		'
Principal amount of tax-exempt revenue bonds held as short-term investment	'		'		'		163
Proceeds received from the remarketing of certain Kentucky tax-exempt revenue bonds	'		'		163		'
Nuclear Decommissioning Trust Funds [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	497		474		'		'
Gross unrealized gains	370		239		'		'
Gross unrealized losses	3		1		'		'
Fair value	864		712		'		'
Nuclear Decommissioning Trust Funds (Numeric) [Abstract]	'		'		'		'
Percentage of shortfall PPL Susquehanna would be obligated to fund	90.00%		'		'		'
Impairments recorded to NDT securities	'		'		6		'
Nuclear Decommissioning Trust Funds [Member] | Cash And Cash Equivalents [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	14		11		'		'
Gross unrealized gains	'		'		'		'
Gross unrealized losses	'		'		'		'
Fair value	14		11		'		'
Nuclear Decommissioning Trust Funds [Member] | Equity Securities [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	265		252		'		'
Gross unrealized gains	363		220		'		'
Gross unrealized losses	'		'		'		'
Fair value	628		472		'		'
Nuclear Decommissioning Trust Funds [Member] | Debt Securities [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	217		211		'		'
Gross unrealized gains	7		19		'		'
Gross unrealized losses	3		1		'		'
Fair value	221		229		'		'
Nuclear Decommissioning Trust Funds [Member] | Receivables Payables Net [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	1		'		'		'
Gross unrealized gains	'		'		'		'
Gross unrealized losses	'		'		'		'
Fair value	1		'		'		'
Auction Rate Securities [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	20		20		'		'
Gross unrealized gains	'		'		'		'
Gross unrealized losses	1		1		'		'
Fair value	19		19		'		'
PPL Energy Supply LLC [Member]	'		'		'		'
Available-for-Sale Securities Scheduled Maturity Dates of Debt Securities (Details) [Abstract]	'		'		'		'
Amortized cost - maturity less than 1 year	7		'		'		'
Amortized cost - maturity between 1 and 5 years	97		'		'		'
Amortized cost - maturity between 6 and 10 years	54		'		'		'
Amortized cost - maturity in excess of 10 years	76		'		'		'
Amortized cost total	234		'		'		'
Fair value - maturity less than 1 year	7		'		'		'
Fair value - maturity between 1 and 5 years	99		'		'		'
Fair value - maturity between 6 and 10 years	55		'		'		'
Fair value - maturity in excess of 10 years	76		'		'		'
Fair value total	237		'		'		'
Available-for-Sale Securities Proceeds From and Realized Gains and Losses (Details) [Abstract]	'		'		'		'
Proceeds from sales of NDT securities	144		139		156		'
Other proceeds from sales	'		3		'		'
Gross realized gains	17	[1]	29	[1]	28	[1]	'
Gross realized losses	7	[1]	21	[1]	16	[1]	'
PPL Energy Supply LLC [Member] | Nuclear Decommissioning Trust Funds [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	497		474		'		'
Gross unrealized gains	370		239		'		'
Gross unrealized losses	3		1		'		'
Fair value	864		712		'		'
Nuclear Decommissioning Trust Funds (Numeric) [Abstract]	'		'		'		'
Percentage of shortfall PPL Susquehanna would be obligated to fund	90.00%		'		'		'
Impairments recorded to NDT securities	'		'		6		'
PPL Energy Supply LLC [Member] | Nuclear Decommissioning Trust Funds [Member] | Cash And Cash Equivalents [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	14		11		'		'
Gross unrealized gains	'		'		'		'
Gross unrealized losses	'		'		'		'
Fair value	14		11		'		'
PPL Energy Supply LLC [Member] | Nuclear Decommissioning Trust Funds [Member] | Equity Securities [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	265		252		'		'
Gross unrealized gains	363		220		'		'
Gross unrealized losses	'		'		'		'
Fair value	628		472		'		'
PPL Energy Supply LLC [Member] | Nuclear Decommissioning Trust Funds [Member] | Debt Securities [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	217		211		'		'
Gross unrealized gains	7		19		'		'
Gross unrealized losses	3		1		'		'
Fair value	221		229		'		'
PPL Energy Supply LLC [Member] | Nuclear Decommissioning Trust Funds [Member] | Receivables Payables Net [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	1		'		'		'
Gross unrealized gains	'		'		'		'
Gross unrealized losses	'		'		'		'
Fair value	1		'		'		'
PPL Energy Supply LLC [Member] | Auction Rate Securities [Member]	'		'		'		'
Available-for-Sale Securities Balance Sheet (Details) [Abstract]	'		'		'		'
Amortized cost	17		17		'		'
Gross unrealized gains	'		'		'		'
Gross unrealized losses	1		1		'		'
Fair value	16		16		'		'
LG And E And KU Energy LLC [Member]	'		'		'		'
Short Term Investments (Numeric) [Abstract]	'		'		'		'
Principal amount of tax-exempt revenue bonds held as short-term investment	'		'		'		163
Proceeds received from the remarketing of certain Kentucky tax-exempt revenue bonds	'		'		163		'
Louisville Gas And Electric Co [Member]	'		'		'		'
Short Term Investments (Numeric) [Abstract]	'		'		'		'
Principal amount of tax-exempt revenue bonds held as short-term investment	'		'		'		163
Proceeds received from the remarketing of certain Kentucky tax-exempt revenue bonds	'		'		$163		'
[1]	Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	($1,940)	($788)	($479)
Amounts arising during the period	323	'	'
Reclassifications from accumulated other comprehensive income	52	'	'
Net other comprehensive income during the period	375	-1,152	-309
Balance at end of period	-1,565	-1,940	-788
Foreign Currency Translation Adjustments [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	-149	-243	-195
Amounts arising during the period	138	'	'
Reclassifications from accumulated other comprehensive income	'	'	'
Net other comprehensive income during the period	138	94	-48
Balance at end of period	-11	-149	-243
Available For Sale Securities Unrealized Gains (Losses) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	112	90	88
Amounts arising during the period	67	'	'
Reclassifications from accumulated other comprehensive income	-6	'	'
Net other comprehensive income during the period	61	22	2
Balance at end of period	173	112	90
Qualifying Derivatives Unrealized Gains (Losses) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	132	527	695
Amounts arising during the period	45	'	'
Reclassifications from accumulated other comprehensive income	-83	'	'
Net other comprehensive income during the period	-38	-395	-168
Balance at end of period	94	132	527
Equity Investees Accumulated Other Comprehensive Income [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	1	-1	-4
Amounts arising during the period	'	'	'
Reclassifications from accumulated other comprehensive income	'	'	'
Net other comprehensive income during the period	'	2	3
Balance at end of period	1	1	-1
Defined Benefit Plans Prior Service Costs [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	-14	-25	-32
Amounts arising during the period	2	'	'
Reclassifications from accumulated other comprehensive income	6	'	'
Net other comprehensive income during the period	8	11	7
Balance at end of period	-6	-14	-25
Defined Benefit Plans Actuarial Gain (Loss) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	-2,023	-1,137	-1,032
Amounts arising during the period	71	'	'
Reclassifications from accumulated other comprehensive income	135	'	'
Net other comprehensive income during the period	206	-886	-105
Balance at end of period	-1,817	-2,023	-1,137
Defined Benefit Plans Transition Assset Obligation [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	1	1	1
Amounts arising during the period	'	'	'
Reclassifications from accumulated other comprehensive income	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	1	1	1
PPL Energy Supply LLC [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	48	487	-355
Amounts arising during the period	140	'	'
Distribution of membership interest In PPL Global	'	'	939
Reclassifications from accumulated other comprehensive income	-111	'	'
Net other comprehensive income during the period	29	-439	-97
Balance at end of period	77	48	487
PPL Energy Supply LLC [Member] | Foreign Currency Translation Adjustments [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	-195
Amounts arising during the period	'	'	'
Distribution of membership interest In PPL Global	'	'	195
Reclassifications from accumulated other comprehensive income	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	'	'	'
PPL Energy Supply LLC [Member] | Available For Sale Securities Unrealized Gains (Losses) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	112	90	88
Amounts arising during the period	67	'	'
Distribution of membership interest In PPL Global	'	'	'
Reclassifications from accumulated other comprehensive income	-6	'	'
Net other comprehensive income during the period	61	22	2
Balance at end of period	173	112	90
PPL Energy Supply LLC [Member] | Qualifying Derivatives Unrealized Gains (Losses) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	211	606	733
Amounts arising during the period	'	'	'
Distribution of membership interest In PPL Global	'	'	-41
Reclassifications from accumulated other comprehensive income	-123	'	'
Net other comprehensive income during the period	-123	-395	-86
Balance at end of period	88	211	606
PPL Energy Supply LLC [Member] | Equity Investees Accumulated Other Comprehensive Income [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	-3
Amounts arising during the period	'	'	'
Distribution of membership interest In PPL Global	'	'	'
Reclassifications from accumulated other comprehensive income	'	'	'
Net other comprehensive income during the period	'	'	3
Balance at end of period	'	'	'
PPL Energy Supply LLC [Member] | Defined Benefit Plans Prior Service Costs [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	-10	-16	-23
Amounts arising during the period	2	'	'
Distribution of membership interest In PPL Global	'	'	5
Reclassifications from accumulated other comprehensive income	4	'	'
Net other comprehensive income during the period	6	6	2
Balance at end of period	-4	-10	-16
PPL Energy Supply LLC [Member] | Defined Benefit Plans Actuarial Gain (Loss) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	-265	-193	-955
Amounts arising during the period	71	'	'
Distribution of membership interest In PPL Global	'	'	780
Reclassifications from accumulated other comprehensive income	14	'	'
Net other comprehensive income during the period	85	-72	-18
Balance at end of period	-180	-265	-193
PPL Energy Supply LLC [Member] | Defined Benefit Plans Transition Assset Obligation [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	'
Amounts arising during the period	'	'	'
Distribution of membership interest In PPL Global	'	'	'
Reclassifications from accumulated other comprehensive income	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	'	'	'
LG And E And KU Energy LLC [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	-15	4	6
Amounts arising during the period	28	'	'
Net other comprehensive income during the period	28	-19	-2
Balance at end of period	13	-15	4
LG And E And KU Energy LLC [Member] | Foreign Currency Translation Adjustments [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	'
Amounts arising during the period	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	'	'	'
LG And E And KU Energy LLC [Member] | Available For Sale Securities Unrealized Gains (Losses) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	'
Amounts arising during the period	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	'	'	'
LG And E And KU Energy LLC [Member] | Qualifying Derivatives Unrealized Gains (Losses) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	'
Amounts arising during the period	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	'	'	'
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	1	'	'
Amounts arising during the period	'	'	'
Net other comprehensive income during the period	'	1	'
Balance at end of period	1	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	-2	-2	'
Amounts arising during the period	'	'	'
Net other comprehensive income during the period	'	'	-2
Balance at end of period	-2	-2	-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	-14	6	6
Amounts arising during the period	28	'	'
Net other comprehensive income during the period	28	-20	'
Balance at end of period	14	-14	6
LG And E And KU Energy LLC [Member] | Defined Benefit Plans Transition Assset Obligation [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Balance at beginning of period	'	'	'
Amounts arising during the period	'	'	'
Net other comprehensive income during the period	'	'	'
Balance at end of period	'	'	'

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

'

'

'

'

'

'

'

'

($1,006)

($961)

($898)

Other Income (Expense) - net

'

'

'

'

'

'

'

'

-23

-39

4

Total Pre-tax

'

'

'

'

'

'

'

'

1,309

2,082

2,201

Income Taxes

'

'

'

'

'

'

'

'

-180

-545

-691

Total After-Tax

-98

[1],[2]

410

[1]

404

[1]

413

[1]

360

[1]

355

[1]

277

[1]

545

[1]

1,129

1,537

1,510

Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-52

'

'

Available For Sale Securities [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

'

'

'

Energy purchases

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

'

'

'

'

'

'

'

'

'

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

10

'

'

Other

'

'

'

'

'

'

'

'

'

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

10

'

'

Income Taxes

'

'

'

'

'

'

'

'

-4

'

'

Total After-Tax

'

'

'

'

'

'

'

'

6

'

'

Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

263

'

'

Energy purchases

'

'

'

'

'

'

'

'

-58

'

'

Interest Expense

'

'

'

'

'

'

'

'

-19

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

-28

'

'

Other

'

'

'

'

'

'

'

'

5

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

163

'

'

Income Taxes

'

'

'

'

'

'

'

'

-80

'

'

Total After-Tax

'

'

'

'

'

'

'

'

83

'

'

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]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

'

'

'

Energy purchases

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

'

'

'

'

'

'

'

'

-20

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

'

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

-20

'

'

Income Taxes

'

'

'

'

'

'

'

'

1

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-19

'

'

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]

'

'

'

'

'

'

'

'

'

'

'

Energy purchases

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

'

'

'

'

'

'

'

'

1

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

-28

'

'

Other

'

'

'

'

'

'

'

'

'

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

-27

'

'

Income Taxes

'

'

'

'

'

'

'

'

4

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-23

'

'

Qualifying Derivatives [Member] | Energy Commodities [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

263

'

'

Energy purchases

'

'

'

'

'

'

'

'

-58

'

'

Interest Expense

'

'

'

'

'

'

'

'

'

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

5

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

210

'

'

Income Taxes

'

'

'

'

'

'

'

'

-85

'

'

Total After-Tax

'

'

'

'

'

'

'

'

125

'

'

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

'

'

'

'

'

'

'

'

-194

'

'

Income Taxes

'

'

'

'

'

'

'

'

53

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-141

'

'

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

'

'

'

'

'

'

'

'

-10

'

'

Income Taxes

'

'

'

'

'

'

'

'

4

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-6

'

'

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

'

'

'

'

'

'

'

'

-184

'

'

Income Taxes

'

'

'

'

'

'

'

'

49

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-135

'

'

PPL Energy Supply LLC [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

'

'

'

'

'

'

'

'

-171

-168

-174

Other Income (Expense) - net

'

'

'

'

'

'

'

'

30

18

23

Total Pre-tax

'

'

'

'

'

'

'

'

-371

738

1,212

Income Taxes

'

'

'

'

'

'

'

'

142

[3]

-263

[3]

-445

[3]

Total After-Tax

'

'

'

'

'

'

'

'

-229

475

767

PPL Energy Supply LLC [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total After-Tax

'

'

'

'

'

'

'

'

111

'

'

PPL Energy Supply LLC [Member] | Available For Sale Securities [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

'

'

'

Energy purchases

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

'

'

'

'

'

'

'

'

'

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

10

'

'

Other

'

'

'

'

'

'

'

'

'

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

10

'

'

Income Taxes

'

'

'

'

'

'

'

'

-4

'

'

Total After-Tax

'

'

'

'

'

'

'

'

6

'

'

PPL Energy Supply LLC [Member] | 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]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

'

'

'

PPL Energy Supply LLC [Member] | Qualifying Derivatives [Member] | Energy Commodities [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Unregulated wholesale energy

'

'

'

'

'

'

'

'

263

'

'

Energy purchases

'

'

'

'

'

'

'

'

-58

'

'

Interest Expense

'

'

'

'

'

'

'

'

'

'

'

Other Income (Expense) - net

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

2

'

'

Total Pre-tax

'

'

'

'

'

'

'

'

207

'

'

Income Taxes

'

'

'

'

'

'

'

'

-84

'

'

Total After-Tax

'

'

'

'

'

'

'

'

123

'

'

PPL Energy Supply LLC [Member] | 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

'

'

'

'

'

'

'

'

-31

'

'

Income Taxes

'

'

'

'

'

'

'

'

13

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-18

'

'

PPL Energy Supply LLC [Member] | 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

'

'

'

'

'

'

'

'

-7

'

'

Income Taxes

'

'

'

'

'

'

'

'

3

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-4

'

'

PPL Energy Supply LLC [Member] | 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

'

'

'

'

'

'

'

'

-24

'

'

Income Taxes

'

'

'

'

'

'

'

'

10

'

'

Total After-Tax

'

'

'

'

'

'

'

'

-14

'

'

Kentucky Utilities Co [Member]

'

'

'

'

'

'

'

'

'

'

'

Affected Line Item on the Statements of Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Energy purchases

'

'

'

'

'

'

'

'

-22

-32

-29

Interest Expense

'

'

'

'

'

'

'

'

-70

-69

-70

Other Income (Expense) - net

'

'

'

'

'

'

'

'

-3

-8

-1

Total Pre-tax

'

'

'

'

'

'

'

'

360

215

282

Income Taxes

'

'

'

'

'

'

'

'

($132)

[4]

($78)

[4]

($104)

[4]

[1]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[2]

Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements for additional information.

[3]

Excludes current and deferred federal, state and foreign tax expense (benefit) recorded to Discontinued Operations of $3 million in 2011. Also, excludes federal, state and foreign tax expense (benefit) recorded to OCI of $47 million in 2013, $(267) million in 2012 and $(83) million in 2011. The deferred tax benefit of operating loss carryforwards was insignificant for 2011.

[4]

Excludes deferred federal and state tax (benefit) recorded to OCI of less than $1 million in 2013 and $1 million in 2012.

SCHEDULE_I_CONDENSED_UNCONSOLI1

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Operating Revenues

'

'

'

'

'

'

'

'

'

'

'

Operating Revenues

$2,848

[1]

$3,105

[1]

$3,450

[1]

$2,457

[1]

$3,222

[1]

$2,403

[1]

$2,549

[1]

$4,112

[1]

$11,860

$12,286

$12,737

Operating Expenses [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Other operation and maintenance

'

'

'

'

'

'

'

'

2,825

2,835

2,667

Total Operating Expenses

'

'

'

'

'

'

'

'

9,521

9,177

9,636

Operating Income (Loss)

31

[1],[2]

857

[1]

758

[1]

693

[1]

822

[1]

664

[1]

572

[1]

1,051

[1]

2,339

3,109

3,101

Equity in earnings of subsidiaries

'

'

'

'

'

'

'

'

'

-8

1

Other Income (Expense) - net

'

'

'

'

'

'

'

'

-23

-39

4

Interest Expense

'

'

'

'

'

'

'

'

1,006

961

898

Income (Loss) Before Income Taxes

'

'

'

'

'

'

'

'

1,309

2,082

2,201

Income Tax Expense (Benefit)

'

'

'

'

'

'

'

'

180

545

691

Net Income (Loss)

-98

[1],[2]

410

[1]

405

[1]

413

[1]

359

[1]

355

[1]

271

[1]

541

[1]

1,130

1,526

1,495

Comprehensive Income (Loss)

'

'

'

'

'

'

'

'

1,505

374

1,186

L G And E And K U Energy L L C Unconsolidated [Member]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenues

'

'

'

'

'

'

'

'

'

'

'

Operating Revenues

'

'

'

'

'

'

'

'

'

'

'

Operating Expenses [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Other operation and maintenance

'

'

'

'

'

'

'

'

'

3

'

Total Operating Expenses

'

'

'

'

'

'

'

'

'

3

'

Operating Income (Loss)

'

'

'

'

'

'

'

'

'

-3

'

Equity in earnings of subsidiaries

'

'

'

'

'

'

'

'

376

234

267

Interest Income from Affiliates

'

'

'

'

'

'

'

'

5

10

29

Interest Expense

'

'

'

'

'

'

'

'

39

39

31

Interest Expense with Affiliates

'

'

'

'

'

'

'

'

3

2

2

Income (Loss) Before Income Taxes

'

'

'

'

'

'

'

'

339

200

263

Income Tax Expense (Benefit)

'

'

'

'

'

'

'

'

-8

-19

-2

Net Income (Loss)

'

'

'

'

'

'

'

'

347

219

265

Comprehensive Income (Loss)

'

'

'

'

'

'

'

'

$375

$200

$263

[1]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[2]

Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements for additional information.

SCHEDULE_I_CONDENSED_UNCONSOLI2

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Flows from Operating Activities	'	'	'
Net cash provided by (used in) operating activities	$2,857	$2,764	$2,507
Cash Flows from Investing Activities	'	'	'
Net cash provided by (used in) investing activities	-4,295	-3,123	-7,952
Cash Flows from Financing Activities	'	'	'
Net increase (decrease) in short-term debt	49	74	-125
Retirement of long-term debt	-747	-108	-1,210
Issuance of long-term debt	2,038	1,223	5,745
Debt-issuance costs	-49	-17	-102
Payment of common stock dividends	-878	-833	-746
Net cash provided by (used in) financing activities	1,631	48	5,767
Net Increase (Decrease) in Cash and Cash Equivalents	201	-301	277
Cash and Cash Equivalents at Beginning of Period	901	1,202	925
Cash and Cash Equivalents at End of Period	1,102	901	1,202
L G And E And K U Energy L L C Unconsolidated [Member]	'	'	'
Cash Flows from Operating Activities	'	'	'
Net cash provided by (used in) operating activities	136	364	346
Cash Flows from Investing Activities	'	'	'
Capital contributions to affiliated subsidiaries	-243	'	'
Net (increase) decrease in notes receivable from affiliates	-122	-15	-63
Net cash provided by (used in) investing activities	-365	-15	-63
Cash Flows from Financing Activities	'	'	'
Net increase (decrease) in short-term debt	75	'	'
Issuance of long-term debt	'	'	250
Contributions from member	243	'	'
Distributions to member	-254	-155	-533
Net increase (decrease) in notes payable to affiliates	171	-196	'
Net cash provided by (used in) financing activities	235	-351	-283
Net Increase (Decrease) in Cash and Cash Equivalents	6	-2	'
Cash and Cash Equivalents at Beginning of Period	'	2	2
Cash and Cash Equivalents at End of Period	6	'	2
Supplemental Disclosures of Cash Flow Information:	'	'	'
Cash Dividends Received from Affiliated Subsidiaries	$223	$175	$207

SCHEDULE_I_CONDENSED_UNCONSOLI3

SCHEDULE I - CONDENSED UNCONSOLIDATED BALANCE SHEETS (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Millions, unless otherwise specified
Current Assets	'	'	'	'
Cash and cash equivalents	$1,102	$901	$1,202	$925
Accounts receivable	923	745	'	'
Other current assets	37	19	'	'
Total Current Assets	5,153	5,068	'	'
Other Noncurrent Assets	'	'	'	'
Other noncurrent assets	357	637	'	'
Total Other Noncurrent Assets	7,112	7,775	'	'
Total Assets	46,259	43,634	'	'
Current Liabilities	'	'	'	'
Short-term debt	701	652	'	'
Taxes	114	90	'	'
Other current liabilities	998	1,219	'	'
Total Current Liabilities	4,912	5,625	'	'
Long-term Debt	'	'	'	'
Long-term Debt	20,592	18,725	'	'
Total Deferred Credits and Other Noncurrent Liabilities	8,289	8,786	'	'
L G And E And K U Energy L L C Unconsolidated [Member]	'	'	'	'
Current Assets	'	'	'	'
Cash and cash equivalents	6	'	2	2
Accounts receivable	2	'	'	'
Accounts receivable from affiliates	11	4	'	'
Notes receivable from affiliates	1,682	1,560	'	'
Other current assets	10	1	'	'
Total Current Assets	1,711	1,565	'	'
Investments	'	'	'	'
Affiliated companies at equity	4,519	4,096	'	'
Other Noncurrent Assets	'	'	'	'
Deferred income taxes	170	184	'	'
Other noncurrent assets	6	7	'	'
Total Other Noncurrent Assets	176	191	'	'
Total Assets	6,406	5,852	'	'
Current Liabilities	'	'	'	'
Short-term debt	75	'	'	'
Notes payable to affiliates	'	25	'	'
Accounts payable to affiliates	843	906	'	'
Taxes	12	8	'	'
Other current liabilities	6	6	'	'
Total Current Liabilities	936	945	'	'
Long-term Debt	'	'	'	'
Long-term Debt	1,121	1,121	'	'
Notes payable to affiliates	196	'	'	'
Total Long-term Debt	1,317	1,121	'	'
Total Deferred Credits and Other Noncurrent Liabilities	3	'	'	'
Members Equity	4,150	3,786	'	'
Total Liabilities and Equity	$6,406	$5,852	'	'

SCHEDULE_I_NOTES_TO_CONDENSED_

SCHEDULE I - NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS (Details) (LKE Guarantee [Member], Indemnification Guarantee [Member], Indemnification Of Lease Termination And Other Divestitures [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Condensed Unconsolidated Financial Statements [Line Items]	'
Term of guarantee (in years)	'12
Expiration date minimum	'2021
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	'2023
Charge recorded in discontinued operations relating to certain indemnification, pre-tax	9
Charge recorded in discontinued operations relating to certain indemnification, after-tax	5
LG&E and KU Energy LLC Unconsolidated	'
Condensed Unconsolidated Financial Statements [Line Items]	'
Term of guarantee (in years)	'12
Expiration date minimum	'2021
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	'2023
Charge recorded in discontinued operations relating to certain indemnification, pre-tax	9
Charge recorded in discontinued operations relating to certain indemnification, after-tax	$5

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Details) (USD $)

1 Months Ended

3 Months Ended

12 Months Ended

In Millions, except Per Share data, unless otherwise specified

Nov. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Quarterly Financial Information (Unaudited) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Operating revenues

'

$2,848

[1]

$3,105

[1]

$3,450

[1]

$2,457

[1]

$3,222

[1]

$2,403

[1]

$2,549

[1]

$4,112

[1]

$11,860

$12,286

$12,737

Operating income

'

31

[1],[2]

857

[1]

758

[1]

693

[1]

822

[1]

664

[1]

572

[1]

1,051

[1]

2,339

3,109

3,101

Income from continuing operations after income taxes

'

-98

[1],[2]

410

[1]

404

[1]

413

[1]

360

[1]

355

[1]

277

[1]

545

[1]

1,129

1,537

1,510

Income (loss) from discontinued operations

'

'

1

[1]

1

[1]

'

'

'

-6

[1]

'

2

-6

2

Net income

'

-98

[1],[2]

411

[1]

405

[1]

413

[1]

360

[1]

355

[1]

271

[1]

545

[1]

1,131

1,531

1,512

Net income attributable to PPL shareowners

'

-98

[1],[2]

410

[1]

405

[1]

413

[1]

359

[1]

355

[1]

271

[1]

541

[1]

1,130

1,526

1,495

Income from continuing operations after income taxes available to PPL common shareowners: [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Basic (in dollars per share)

'

($0.16)

[1],[2],[3]

$0.65

[1],[3]

$0.68

[1],[3]

$0.70

[1],[3]

$0.61

[1],[3]

$0.61

[1],[3]

$0.47

[1],[3]

$0.93

[1],[3]

$1.85

$2.62

$2.70

Diluted (in dollars per share)

'

($0.16)

[1],[2],[3],[4]

$0.62

[1],[3],[4]

$0.63

[1],[3],[4]

$0.65

[1],[3],[4]

$0.60

[1],[3]

$0.61

[1],[3]

$0.47

[1],[3]

$0.93

[1],[3]

$1.76

$2.61

$2.70

Dividends declared per share of common stock (in dollars per share)

$0.37

$0.37

[1],[5]

$0.37

[1],[5]

$0.37

[1],[5]

$0.37

[1],[5]

$0.36

[1],[5]

$0.36

[1],[5]

$0.36

[1],[5]

$0.36

[1],[5]

$1.47

$1.44

$1.40

Net income available to PPL common shareowners: [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Basic (in dollars per share)

'

($0.16)

[1],[2],[3]

$0.65

[1],[3]

$0.68

[1],[3]

$0.70

[1],[3]

$0.61

[1],[3]

$0.61

[1],[3]

$0.46

[1],[3]

$0.93

[1],[3]

$1.85

$2.61

$2.71

Diluted (in dollars per share)

'

($0.16)

[1],[2],[3],[4]

$0.62

[1],[3],[4]

$0.63

[1],[3],[4]

$0.65

[1],[3],[4]

$0.60

[1],[3]

$0.61

[1],[3]

$0.46

[1],[3]

$0.93

[1],[3]

$1.76

$2.60

$2.70

Price per common share: [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

High (in dollars per share)

'

$31.79

[1]

$32.09

[1]

$33.55

[1]

$31.35

[1]

$30.18

[1]

$29.98

[1]

$28.44

[1]

$29.85

[1]

'

'

'

Low (in dollars per share)

'

$28.95

[1]

$29.03

[1]

$28.44

[1]

$28.64

[1]

$27.74

[1]

$27.72

[1]

$26.68

[1]

$27.29

[1]

'

'

'

PPL Electric Utilities Corp [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Quarterly Financial Information (Unaudited) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Operating revenues

'

479

[6]

464

[6]

414

[6]

513

[6]

457

[6]

444

[6]

404

[6]

458

[6]

1,870

1,763

1,892

Operating income

'

101

[6]

105

[6]

92

[6]

121

[6]

81

[6]

71

[6]

63

[6]

79

[6]

419

294

348

Net income

'

49

[6]

51

[6]

45

[6]

64

[6]

37

[6]

33

[6]

29

[6]

37

[6]

209

[7]

136

[7]

189

[7]

Net income available to PPL

'

$49

[6]

$51

[6]

$45

[6]

$64

[6]

$37

[6]

$33

[6]

$29

[6]

$33

[6]

$209

$132

$173

[1]

Quarterly results can vary depending on, among other things, weather and the forward pricing of power. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

[2]

Fourth quarter of 2013 includes a charge for the termination of the lease of the Colstrip coal-fired electric generating facility in Montana. See Note 8 to the Financial Statements for additional information.

[3]

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.

[4]

As a result of a reported loss, diluted earnings per share for the three months ended December 31, 2013 exclude incremental shares as they were anti-dilutive.

[5]

PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.

[6]

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.

[7]

Net income approximates comprehensive income.