Talen Energy (TLN) 10-Q 8 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	Apr. 30, 2015
Entity Registrant Name	TALEN ENERGY HOLDINGS, INC.
Entity Central Index Key	1622537
Document Type	10-Q
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		1
Talen Energy Corporation
Entity Registrant Name	TALEN ENERGY CORPORATION
Entity Central Index Key	1622536
Document Type	10-Q
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		1

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating Revenues
Unregulated wholesale energy	$522	($1,457)
Unregulated wholesale energy to affiliate	9	27
Unregulated retail energy	311	350
Energy-related businesses	104	125
Total Operating Revenues	946	-955
Operation
Fuel	351	482
Energy purchases	1	-1,804
Other operation and maintenance	226	229
Depreciation	77	75
Taxes, other than income	15	18
Energy-related businesses	98	124
Total Operating Expenses	768	-876
Operating Income (Loss)	178	-79
Other Income (Expense) - net	7	6
Interest Expense	36	32
Income (Loss) from Continuing Operations Before Income Taxes	149	-105
Income Taxes	53	-47
Income (Loss) from Continuing Operations After Income Taxes	96	-58
Income (Loss) from Discontinued Operations (net of income taxes)	0	-8
Net Income (Loss)	$96	($66)

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income (loss)	$96	($66)
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Available-for-sale securities, net of tax	5	5
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Available-for-sale securities, net of tax	-1	-1
Qualifying derivatives, net of tax	-4	-5
Defined benefit plans:
Prior service costs, net of tax	0	1
Net actuarial loss, net of tax	4	1
Total other comprehensive income (loss)	4	1
Comprehensive income (loss)	$100	($65)

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Tax effect of available for sale securities arising during the period	($6)	($6)
Tax effect of available-for-sale securities reclassified from accumulated other comprehensive income (loss)	1	1
Tax effect of qualifying derivatives reclassified from accumulated other comprehensive income (loss)	3	4
Tax effect of prior service costs reclassified from accumulated other comprehensive income (loss)	0	-1
Tax effect of net actuarial loss reclassified from accumulated other comprehensive income (loss)	($3)	($1)

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash Flows from Operating Activities
Net income (loss)	$96	($66)
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation	77	80
Amortization	46	44
Defined benefit plans - expense	12	8
Deferred income taxes and investment tax credits	13	-121
Impairment of assets	2	18
Unrealized (gains) losses on derivatives, and other hedging activities	-38	229
Other	5	5
Change in current assets and current liabilities
Accounts receivable	-16	-15
Accounts payable	-94	153
Unbilled revenues	77	-92
Fuel, materials and supplies	73	43
Prepayments	34	-10
Taxes payable	30	53
Other	-25	-20
Other operating activities
Defined benefit plans - funding	-74	-30
Other assets	5	-5
Other liabilities	-2	2
Net cash provided by operating activities	221	276
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	-109	-88
Purchases of nuclear plant decommissioning trust investments	-43	-32
Proceeds from the sale of nuclear plant decommissioning trust investments	38	27
Proceeds from the receipt of grants	0	56
Net (increase) decrease in restricted cash and cash equivalents	-7	-344
Other investing activities	-9	-8
Net cash provided by (used in) investing activities	-130	-389
Cash Flows from Financing Activities
Distributions to member	-191	-654
Net increase (decrease) in short-term debt	-30	970
Other financing activities	-1	-1
Net cash provided by (used in) financing activities	-222	315
Net Increase (Decrease) in Cash and Cash Equivalents	-131	202
Cash and Cash Equivalents at Beginning of Period	352	239
Cash and Cash Equivalents at End of Period	$221	$441

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Current Assets
Cash and cash equivalents	$221	$352
Restricted cash and cash equivalents	183	176
Accounts receivable (less reserve:)
Customer	212	186
Other	38	103
Accounts receivable from affiliates	68	36
Unbilled revenues	141	218
Fuel, materials and supplies	382	455
Prepayments	36	70
Price risk management assets	988	1,079
Other current assets	18	26
Total Current Assets	2,287	2,701
Investments
Nuclear plant decommissioning trust funds	965	950
Other investments	30	30
Total Investments	995	980
Property, Plant and Equipment
Generation	11,318	11,318
Nuclear fuel	749	624
Other	293	293
Less: accumulated depreciation	6,340	6,242
Property, plant and equipment, net	6,020	5,993
Construction work in progress	351	443
Total Property, Plant and Equipment, net	6,371	6,436
Other Noncurrent Assets
Goodwill	72	72
Other intangibles	259	257
Price risk management assets	310	239
Other noncurrent assets	72	75
Total Other Noncurrent Assets	713	643
Total Assets	10,366	10,760
Current Liabilities
Short-term debt	600	630
Long-term debt due within one year	535	535
Accounts payable	225	361
Accounts payable to affiliates	34	50
Taxes	58	28
Interest	41	16
Price risk management liabilities	904	1,024
Other current liabilities	179	246
Total Current Liabilities	2,576	2,890
Long-term Debt	1,682	1,683
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,226	1,223
Investment tax credits	26	27
Price risk management liabilities	259	193
Accrued pension obligations	230	299
Asset retirement obligations	423	415
Other deferred credits and noncurrent liabilities	128	123
Total Deferred Credits and Other Noncurrent Liabilities	2,292	2,280
Commitments and Contingent Liabilities
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Member's Equity	3,816	3,907
Total Liabilities and Equity	$10,366	$10,760

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Statement of Financial Position [Abstract]
Accounts receivable reserve for uncollectible accounts	$2	$2

CONDENSED_CONSOLIDATED_STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Increase (Decrease) in Members' Equity
Balance at beginning of period	$3,907	$4,798
Net income (loss)	96	-66
Other comprehensive income (loss)	4	1
Distributions	-191
Contributions from member		-654
Balance at end of period	$3,816	$4,079

Business_and_Basis_of_Presenta

Business and Basis of Presentation	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Business and Basis of Presentation	Business and Basis of Presentation
	Capitalized terms and abbreviations appearing in the unaudited notes to condensed consolidated financial statements are defined in the glossary.  Dollars are in millions, unless otherwise noted.
	See "Business-Anticipated Spinoff from PPL" below for discussion of the June 2014 executed definitive agreements of PPL and PPL Energy Supply with affiliates of Riverstone to combine their competitive power generation businesses into a new, stand-alone, publicly traded company named Talen Energy. It is expected that after completion of the spinoff merger and combination, Holdco will request to have its Securities Exchange Act filing requirements suspended as it will be a wholly owned subsidiary of Talen Energy. On April 29, 2015, PPL's Board of Directors declared the distribution of Holdco to PPL's shareowners of record on May 20, 2015, with the spinoff to occur on June 1, 2015.
	Holdco's and Talen Energy's obligations to report under the Securities Exchange Act of 1934 commenced on May 1, 2015, the date the Registration Statement on Form S-1 of Holdco and Talen Energy was declared effective by the SEC. Because this was prior to the completion of the spinoff and the acquisition of RJS Power, the financial information presented in this Quarterly Report on Form 10-Q represents only legacy PPL Energy Supply activity for the periods presented. Following completion of the spinoff, Talen Energy will report consolidated financial results of PPL Energy Supply (which will be renamed Talen Energy Supply, LLC following completion of the spinoff transaction) and RJS Power for the periods subsequent to the combination.
	Business-Anticipated Spinoff from PPL
	PPL Energy Supply, headquartered in Allentown, Pennsylvania, is an indirect wholly owned subsidiary of PPL and is an energy company that, through its principal subsidiaries, is primarily engaged in the competitive generation and marketing of electricity in two key markets - the northeastern and northwestern U.S.
	In June 2014, PPL and PPL Energy Supply executed definitive agreements with affiliates of Riverstone to combine their competitive power generation businesses into a new, stand-alone, publicly traded company named Talen Energy.  Under the terms of the agreements, at closing, PPL will spin off to PPL shareowners a newly formed entity, Holdco, which at such time will own all of the membership interests of PPL Energy Supply and all of the common stock of Talen Energy. Immediately following the spinoff, Holdco will merge with a special purpose subsidiary of Talen Energy, with Holdco continuing as the surviving company to the merger and as a wholly owned subsidiary of Talen Energy and the sole owner of PPL Energy Supply. Substantially contemporaneous with the spinoff and merger, RJS Power will be contributed by its owners to become a subsidiary of Talen Energy.  Following completion of these transactions, PPL shareowners will own 65% of Talen Energy and affiliates of Riverstone will own 35%.  PPL will have no continuing ownership interest in, control of, or affiliation with Talen Energy.  The transaction is subject to customary closing conditions, including receipt of required regulatory approvals from the NRC, FERC, DOJ and PUC, all of which were received by mid-April 2015.  In addition, there must be available, subject to certain conditions, at least $1 billion of undrawn credit capacity under a revolving credit or similar facility of Talen Energy or one or more of its subsidiaries. Any letters of credit or other credit support measures posted in connection with energy marketing and trading transactions at the time of the spinoff are excluded from this calculation.
	In connection with the FERC approval, PPL and RJS Power agreed that within 12 months after closing of the transaction, Talen Energy will divest approximately 1,300 MW of generating assets in one of two groups of assets (from PPL Energy Supply's existing portfolio, this includes either the Holtwood and Wallenpaupack hydroelectric facilities or the Ironwood facility), and limit PJM energy market offers from assets it would retain in the other group to cost-based offers.
	On April 29, 2015, PPL's Board of Directors declared the distribution of Holdco to PPL's shareowners of record on May 20, 2015, with the spinoff to occur on June 1, 2015.
	Following the announcement of the transaction to form Talen Energy, efforts were initiated to identify the appropriate staffing for Talen Energy following completion of the spinoff.  Organizational plans were substantially completed in 2014. The new organizational plans identified the need to resize and restructure the PPL Energy Supply organization and as a result, in 2014, estimated charges for employee separation benefits were recorded. See Note 8 in PPL Energy Supply's 2014 Form 10-K for additional information. The separation benefits include cash severance compensation, lump sum COBRA reimbursement payments and outplacement services.  Most separations and payment of separation benefits are expected to be completed by the end of 2015. At March 31, 2015 and December 31, 2014, the recorded liabilities related to the separation benefits were $3 million and $9 million, which are included in "Other current liabilities" on the Balance Sheets.
	Additional employee-related costs to be incurred primarily include accelerated stock-based compensation and pro-rated performance-based cash incentive and stock-based compensation awards, primarily for PPL Energy Supply employees and for PPL employees who have become PPL Energy Supply employees in connection with the transaction.  These costs will be recognized at the spinoff closing date.  PPL Energy Supply estimates these additional costs will be in the range of $30 million to $40 million.
	In accordance with business combination accounting guidance, PPL Energy Supply will treat the combination with RJS Power as an acquisition and PPL Energy Supply will be considered the acquirer of RJS Power.
	Interim Financial Statements
	The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnotes required by GAAP for complete financial statements.  In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed consolidated financial statements.  All adjustments are of a normal recurring nature, except as otherwise disclosed.  PPL Energy Supply's Balance Sheet at December 31, 2014 is derived from PPL Energy Supply's 2014 audited Balance Sheet.  The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in PPL Energy Supply's 2014 Form 10-K.  The results of operations for the three months ended March 31, 2015 are not necessarily indicative of the results to be expected for the full year ending December 31, 2015 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.
	The classification of certain prior period amounts has been changed to conform to the presentation in the March 31, 2015 financial statements.
	"Income (Loss) from Discontinued Operations (net of income taxes)" for the three months ended March 31, 2014 on the Statement of Income includes the activities of PPL Montana's hydroelectric generating facilities sold in the fourth quarter of 2014.  See Note 5 for additional information.  The Statements of Cash Flows do not separately report the cash flows of the Discontinued Operations.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies
	The following accounting policy disclosures represent updates to Note 1 in PPL Energy Supply's 2014 Form 10-K and should be read in conjunction with those disclosures.
	Accounts Receivable
	In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers (including PPL EnergyPlus) at a discount, which reflects a provision for uncollectible accounts.  PPL EnergyPlus has no continuing involvement or interest in its accounts receivable purchased by PPL Electric.  During the three months ended March 31, 2015 and 2014, PPL Electric purchased $93 million and $105 million of accounts receivable from PPL EnergyPlus.
	New Accounting Guidance Adopted
	Reporting of Discontinued Operations
	Effective January 1, 2015, PPL Energy Supply prospectively adopted accounting guidance that changes the criteria for determining what should be classified as a discontinued operation and the related presentation and disclosure requirements. A discontinued operation may include a component of an entity or a group of components of an entity, or a business activity. A disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has (or will have) a major effect on the entity's operations and financial results when any of the following occurs: (1) The components of an entity or a group of components of an entity meets the criteria to be classified as held for sale, (2) The component of an entity or a group of components of an entity is disposed of by sale, or (3) The component of an entity or a group of components of an entity is disposed of other than by sale (for example, by abandonment or in a distribution to owners in a spinoff).
	The initial adoption of this guidance did not have a significant impact on PPL Energy Supply but will impact the amounts presented as discontinued operations and will enhance the related disclosure requirements related to future disposals or held for sale classifications.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	Reconciliation of income taxes for the periods ended March 31 are:
		Three Months
		2015			2014
	Federal income tax on Income from Continuing Operations Before Income Taxes at statutory tax rate - 35%	$	52		$	(37	)
	Increase (decrease) due to:
	State income taxes, net of federal income tax benefit	5			(12		)
	Federal income tax credits	(3		)	(1		)
	Other	(1		)	3
	Total increase (decrease)	1			(10		)
	Total income taxes	$	53		$	(47	)
	Other
	In February 2015, PPL and the IRS Appeals division reached a settlement on the amount of PPL's refund from its open audits for the years 1998 - 2011. The settlement was required to be reviewed and approved by the Joint Committee on Taxation (JCT) before it is considered final. In April 2015, PPL was notified that the JCT approved PPL's settlement. Subject to a final determination of interest on the refund, PPL Energy Supply expects to record a tax benefit in the range of $7 million to $15 million in the second quarter of 2015 related to the settlement of previously unrecognized tax benefits.

Financing_Activities

Financing Activities

3 Months Ended

Mar. 31, 2015

Debt Disclosure [Abstract]

Financing Activities

Financing Activities

Credit Arrangements and Short-term Debt

PPL Energy Supply maintains credit facilities to enhance liquidity and provide credit support. The following syndicated credit facility was in place at:

31-Mar-15

31-Dec-14

Expiration

Capacity

Borrowed

Letters of

Unused

Borrowed

Letters of

Date

Credit

Capacity

Credit Issued

Issued

Syndicated Credit Facility (a)

Nov-17

$

3,000

$

600

$

267

$

2,133

$

630

$

121

(a)

At March 31, 2015 and December 31, 2014, interest rates on outstanding borrowings were 2.12% and 2.05%. The amounts borrowed are recorded as "Short-term debt" on the Balance Sheets.

The Letter of Credit Facility and Uncommitted Credit Facilities that existed at December 31, 2014 have either expired or matured during the first quarter of 2015. Any previously issued letters of credit under these facilities were either terminated or reissued under the Syndicated Credit Facility at March 31, 2015.

PPL Energy Supply maintains a $500 million Facility Agreement expiring June 2017, which provides PPL Energy Supply 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 March 31, 2015, PPL Energy Supply had 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.  The facility expires in November 2019, but is subject to automatic one-year renewals under certain conditions.  There were $88 million of secured obligations outstanding under this facility at March 31, 2015.

Acquisitions_Development_and_D

Acquisitions, Development and Divestitures	3 Months Ended
	Mar. 31, 2015
Acquisitions Development And Divestitures [Abstract]
Acquisitions, Development and Divestitures	Acquisitions, Development and Divestitures
	PPL Energy Supply from time to time evaluates 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 8 in PPL Energy Supply's 2014 Form 10-K for additional information.
	Discontinued Operations
	Montana Hydro Sale
	In November 2014, PPL Montana completed the sale to NorthWestern of 633 MW of hydroelectric generating facilities located in Montana for approximately $900 million in cash.  The sale included 11 hydroelectric power facilities and related assets.
	Following are the components of Discontinued Operations in the Statement of Income for the period ended March 31.
		Three Months
		2014
	Operating revenues	29
	Interest expense (a)	2
	Income (loss) before income taxes (b)	(10	)
	Income (Loss) from Discontinued Operations (net of income taxes) (b)	(8	)
	(a)	Represents allocated interest expense based upon the discontinued operations share of the net assets of PPL Energy Supply.
	(b)	Includes an impairment charge related to the Kerr Dam Project. See Note 10 for additional information.

Defined_Benefits

Defined Benefits	3 Months Ended
	Mar. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Defined Benefits	Defined Benefits
	Certain net periodic defined benefit costs are applied to accounts that are further distributed between capital and expense, including certain costs allocated to PPL Energy Supply for plans sponsored by PPL Services.
	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL Energy Supply for the periods ended March 31:
		Pension Benefits
		Three Months
		2015			2014
	Service cost	$	1		$	1
	Interest cost	2			2
	Expected return on plan assets	(3		)	(2		)
	Amortization of:
	Actuarial (gain) loss	1			—
	Net periodic defined benefit costs (credits)	$	1		$	1
	In addition to the specific plans it sponsors, PPL Energy Supply is also allocated costs of defined benefit plans sponsored by PPL Services which management believes are reasonable. For the periods ended March 31, Energy Supply was allocated the following net periodic defined benefit costs.
		Three Months
		2015			2014
		$	11		$	7

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies
	Legal Matters
	PPL Energy Supply and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business.  PPL Energy Supply and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted.
	Sierra Club Litigation
	On March 6, 2013, the Sierra Club and MEIC filed a complaint in the U.S. District Court, District of Montana, Billings Division against PPL Montana and the other Colstrip Steam Electric Station (Colstrip) co-owners: Avista Corporation, Puget Sound Energy, Portland General Electric Company, NorthWestern and PacifiCorp. PPL Montana operates Colstrip on behalf of the co-owners. The complaint alleges certain violations of the Clean Air Act, including New Source Review, Title V and opacity requirements and listed 39 separate claims for relief.  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 July 2013, the Sierra Club and MEIC filed an additional Notice of Intent to Sue, identifying additional plant projects that are alleged not to be in compliance with the Clean Air Act and, in September 2013, filed an amended complaint.  The amended complaint dropped all claims regarding pre-2001 plant projects, as well as the plaintiffs' Title V and opacity claims.  It did, 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 in October 2013.  In May 2014, the court dismissed the plaintiffs' independent Best Available Control Technology claims and their Prevention of Significant Deterioration (PSD) claims for three projects, but denied the owners' motion to dismiss the plaintiffs' other PSD claims on statute of limitation grounds.  On August 27, 2014, the Sierra Club and MEIC filed a second amended complaint.  This complaint includes the same causes of action articulated in the first amended complaint, but alleges those claims in regard to only eight projects at the plant between 2001 and 2013.  On September 26, 2014, the Colstrip owners filed an answer to the second amended complaint.  Discovery has been completed.  In April 2015, the plaintiffs indicated they intend to pursue claims related to only four of the remaining projects. In January 2015, trial as to liability in this matter was rescheduled to November 16, 2015. A trial date with respect to remedies, if there is a finding of liability, has not been scheduled. PPL Energy Supply 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 Energy Supply cannot predict the ultimate outcome of this matter at this time.
	Notice of Intent to File Suit
	In October 2014, PPL Energy Supply received a notice letter from the Chesapeake Bay Foundation (CBF) alleging violations of the Clean Water Act and Pennsylvania Clean Streams Law at the Brunner Island generation plant.  The letter was sent to PPL Brunner Island and the PADEP and is intended to provide notice of the alleged violations and CBF's intent to file suit in Federal court after expiration of the 60 day statutory notice period.  Among other things, the letter alleges that PPL Brunner Island failed to comply with the terms of its National Pollutant Discharge Elimination System permit and associated regulations related to the application of nutrient credits to the facility's discharges of nitrogen into the Susquehanna River.  The letter also alleges that PADEP has failed to ensure that credits generated from nonpoint source pollution reduction activities that PPL Brunner Island applies to its discharges meet the eligibility and certification requirements under PADEP's nutrient trading program regulations.  If a court-approved settlement cannot be reached, CBF plans to seek injunctive relief, monetary penalties, fees and costs of litigation.  PPL Energy Supply cannot predict the outcome of this matter.
	Proposed Legislation - Pacific Northwest
	In the first quarter of 2015, legislation was proposed in the State of Oregon to eliminate, over time, the sale of electricity in Oregon from coal-fired generating facilities, and in the State of Washington to provide a means of cost recovery to utility owners of coal-fired generating facilities who commit to retire such facilities. Both proposals are in early stages of consideration and PPL Energy Supply cannot predict whether any legislation seeking to achieve the objectives of the Oregon or Washington legislation will be enacted. Were such legislation to be enacted as proposed, such laws, either individually or collectively, would not be expected to have a material adverse effect on PPL Energy Supply's financial condition or results of operation.
	Regulatory Issues
	New Jersey Capacity Legislation
	In January 2011, New Jersey enacted a law (the Act) that PPL Energy Supply believes would intervene in the wholesale capacity market to create incentives for the development of new, in-state electricity generation facilities 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 encourage necessary generation investment throughout PJM.
	In February 2011, PPL Energy Supply and several other companies filed a complaint in U.S. District Court in New Jersey challenging the Act on the grounds that it violates the Supremacy and Commerce clauses of the U.S. Constitution and requesting relief barring implementation.  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 was appealed to the U.S. Court of Appeals for the Third Circuit (Third Circuit) by CPV Power Development, Inc., Hess Newark, LLC and the State of New Jersey (the Appellants). In September 2014, the Third Circuit affirmed the District Court's decision. In December 2014, the Appellants filed a petition for certiorari before the U.S. Supreme Court. In March 2015, the U.S. Supreme Court requested the U. S. Solicitor General to submit briefs expressing its views as to the issues raised in this case.
	Maryland Capacity Order
	In April 2012, the Maryland Public Service Commission (MD PSC) ordered (Order) three electric utilities in Maryland to enter into long-term contracts to support the construction of new electricity generating facilities in Maryland, the intent of which, PPL Energy Supply believed, was to encourage the construction of new generation 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 Energy Supply and several other companies filed a complaint in U.S. District Court (District Court) in Maryland challenging the Order on the grounds that it violates 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 September 2013, the District Court issued a decision finding the 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 was appealed to the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit) by CPV Power Development, Inc. and the State of Maryland (the Appellants).  In June 2014, the Fourth Circuit affirmed the District Court's opinion and subsequently denied the Appellants' motion for rehearing. In December 2014, the Appellants filed a petition for certiorari before the U.S. Supreme Court. In March 2015, the U.S. Supreme Court requested the U.S. Solicitor General to submit briefs expressing its views as to the issues raised in this case.
	Pacific Northwest Markets
	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, the 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 by the City of Seattle for approximately $50 million.  Hearings before a FERC Administrative Law Judge (ALJ) regarding the City of Seattle's refund claims were completed in October 2013 and briefing was completed in January 2014.  In March 2014, the ALJ issued an initial decision denying the City of Seattle's complaint against PPL Montana.  The initial decision is pending review by the FERC. In June 2015, the United States Court of Appeals for the Ninth Circuit will hold oral arguments on an appeal from the FERC's October 2011 order setting out the remand process that FERC has followed from 2011 to the present.
	Although PPL Energy Supply and its subsidiaries believe they have not engaged in any improper trading or marketing practices affecting the Pacific Northwest markets, 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 Energy Supply cannot estimate a range of reasonably possible losses, if any, related to this matter.
	Electricity - Reliability Standards
	The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk power system.  The FERC oversees this process and independently enforces the Reliability Standards.
	The Reliability Standards have the force and effect of law and apply to certain users of the bulk power electricity system, including electric utility companies, generators and marketers.  Under the Federal Power Act, the FERC may assess civil penalties of up to $1 million per day, per violation, for certain violations.
	PPL Energy Supply monitors its compliance with the Reliability Standards and continues 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 Energy Supply affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time.  PPL Energy Supply cannot predict the outcome of these matters, and cannot estimate a range of reasonably possible losses, if any.
	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 geomagnetically induced currents on implicated transformers.  In May 2013, FERC issued Order No. 779, requiring NERC to submit two types of Reliability Standards for FERC's approval.  The first type would require certain owners and operators of the nation's electricity infrastructure, such as PPL Energy Supply, 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 2014 and was approved in June 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. This proposal was filed by NERC with FERC for approval by January 22, 2015 and is pending consideration by FERC. PPL Energy Supply may be required to make significant expenditures in new equipment or modifications to their facilities to comply with the new requirements.  PPL Energy Supply is 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.
	Environmental Matters
	Due to the environmental issues discussed below or other environmental matters, it may be necessary for PPL Energy Supply to modify, curtail, replace or cease operation of certain facilities or performance of certain operations to comply with statutes, regulations and other requirements of regulatory bodies or courts.  In addition, legal challenges to new environmental permits or rules add to the uncertainty of estimating the future cost of these permits and rules.
	Air
	CSAPR
	The EPA's CSAPR addresses the interstate transport of fine particulates and ozone by regulating emissions of sulfur dioxide and nitrogen oxide. In accordance with an October 2014 U.S. Court of Appeals decision, CSAPR establishes interstate allowance trading programs for sulfur dioxide and nitrogen oxide emissions from fossil-fueled plants in two phases: Phase 1 commenced in January 2015 and Phase 2 commences in 2017. Sulfur dioxide emissions are subject to an annual trading program and nitrogen oxide emissions are subject to annual and ozone season programs. Oral arguments pertaining to outstanding challenges to the EPA's CSAPR were heard before the D.C. Circuit Court during February 2015.
	Although PPL Energy Supply does not anticipate significant costs to comply with these programs, changes in market or operating conditions could result in impacts that are higher than anticipated.
	National Ambient Air Quality Standards
	In 2008, the EPA revised the National Ambient Air Quality Standard for ozone.  As a result, states in the ozone transport region (OTR), including Pennsylvania, are required by the Clean Air Act to impose additional reductions in nitrogen oxide emissions based upon reasonably available control technologies (RACT).  The PADEP is expected to finalize a RACT rule in 2015 requiring some fossil-fueled plants to operate at more stringent nitrogen oxide emission rates. The EPA proposed to further strengthen the ozone standard in November 2014, which could lead to further nitrogen oxide reductions, for PPL Energy Supply's fossil-fueled plants within the OTR. The EPA is under court order to finalize the standard by October 1, 2015. States are also obligated to address interstate transport issues associated with new ozone standards through the establishment of "good neighbor" state implementation plans for those states that are found to contribute significantly to another states' non-attainment. In January 2015, the EPA issued a policy memo to state agencies to facilitate the development of these plans for the 2008 standard, including modeling data defining state contributions. The implementation of such plans could have an impact on the structure and stringency of CSAPR Phase 2 reductions (discussed above), or it could lead to the development of a new ozone transport rule. Non-OTR states are working together to evaluate further nitrogen oxide reductions from fossil-fueled plants with SCRs. The nature and timing of any additional reductions resulting from these evaluations cannot be determined at this time.
	In 2010, the EPA finalized a new National Ambient Air Quality 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). Attainment must be achieved by 2018.  Pursuant to a consent decree between the EPA and Sierra Club approved on March 2, 2015, states are working to finalize designations for other areas by the 2017 or 2020 deadline depending on which designation methodology is used.  PPL Energy Supply anticipates that some of the measures required for compliance with the CSAPR (as discussed above), or the MATS, or the Regional Haze Rules (as discussed below), such as upgraded or new sulfur dioxide scrubbers at certain plants will help to achieve compliance with the new 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 the operations were suspended and the plant was retired in March 2015. In addition, MDEQ recently submitted a request to the EPA for a determination that this area is in attainment. If the EPA agrees with this request, then the deadlines associated with non-attainment would be suspended.
	In December 2012, the EPA issued final rules that tighten the annual National Ambient Air Quality Standard for fine particulates. The rules were challenged by industry groups, and in May 2014 the D.C. Circuit Court upheld them. On January 15, 2015, the EPA published a final rule establishing area designations under the standard. Non-attainment areas in Pennsylvania were identified; however, EPA recently approved state implementation plan revisions for both states that improved these classifications. PPL Energy Supply plants in Pennsylvania will not be expected to make further reductions towards achieving attainment.
	Until final rules are promulgated, non-attainment designations are finalized and state compliance plans are developed, PPL Energy Supply cannot predict the ultimate outcome of the new National Ambient Air Quality standards for ozone, sulfur dioxide and particulate matter.
	MATS
	In February 2012, the EPA finalized the MATS rule requiring reductions of mercury and other hazardous air pollutants from fossil-fuel fired power plants, known as the MATS, with an effective date of April 16, 2012. The rule was challenged by industry groups and states and was upheld by the D.C. Circuit Court, in April 2014. A group of states subsequently petitioned the U.S. Supreme Court to review this decision and on March 25, 2015 oral arguments were heard as to one issue - whether or not EPA unreasonably refused to consider costs when determining whether the MATS regulation was appropriate and necessary. A U.S. Supreme Court decision is expected by June 30, 2015. The rule provides for a three-year compliance deadline with the potential for one- and two-year extensions as provided under the statute. PPL Energy Supply has completed installation or upgrading of relevant environmental controls at affected plants or have received compliance extensions for certain plants as applicable.
	PPL Energy Supply believes that installation of chemical additive systems and other controls may be necessary at certain coal-fired plants in Pennsylvania, 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 at Colstrip are required, the cost of which is not expected to be significant.  Operations were suspended and the Corette plant was retired in March 2015 due to expected market conditions and the costs to comply with the MATS requirements.
	PPL Energy Supply is conducting in-depth reviews of the EPA's amendments to the final rule and certain proposed corrections, none of which are currently expected to be significant.
	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 make reasonable progress every decade, through the application, among other things, 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 regulation has been the western U.S. As for the eastern U.S., the EPA had determined that region-wide reductions under the CSAPR trading program could, in most instances, be utilized under state programs to satisfy BART requirements for sulfur dioxide and nitrogen oxides. However, the EPA's determination is being challenged by environmental groups and others.
	In Montana, the EPA Region 8 developed the regional haze plan as the MDEQ declined to do so. The EPA finalized the Federal Implementation Plan (FIP) for Montana in September 2012.  The final FIP assumed no additional controls for Corette or Colstrip Units 3 and 4, but proposed stricter limits for Corette and Colstrip Units 1 and 2.  PPL Energy Supply was meeting these stricter permit limits at Corette without any significant changes to operations, although other requirements have led to the suspension of operations and retirement of Corette in March 2015 (see "MATS" discussion 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 Energy Supply and environmental groups have appealed the final FIP to the U.S. Court of Appeals for the Ninth Circuit oral argument was heard in May 2014, and the parties are awaiting a decision.
	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.  PPL Energy Supply received various EPA information requests in 2007 and 2009, but has received no further communications from the EPA related to those requests since providing their responses.  In January 2009, 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.  The companies responded to the EPA and the matter remains open. 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.  The EPA requests remain an open matter.  In September 2012, PPL Montana received an information request from the MDEQ regarding Colstrip Unit 1 and other projects.  MDEQ formally suspended this request on June 6, 2014, in consideration of pending litigation (see "Legal Matters - Sierra Club Litigation" above).  PPL Energy Supply 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 any PPL Energy Supply subsidiary is found to have violated NSR regulations by significantly increasing pollutants through a major plant modification, the subsidiary 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 for pollutants not meeting the NAAQS in the area.  The costs to meet such limits, including installation of technology at certain units, could be material.
	Climate Change
	As a result of the April 2007 U.S. Supreme Court decision that the EPA has authority under the Clean Air Act to regulate carbon dioxide 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 carbon dioxide emissions from stationary sources under the NSR and Title V operating permit provisions of the Clean Air Act.  The EPA's rules were challenged in court and on June 23, 2014, the U.S. Supreme Court ruled that the EPA has the authority to regulate carbon dioxide emissions under these provisions of the Clean Air Act but only for stationary sources that would otherwise have been subject to these provisions due to significant increases in emissions of other pollutants.  As a result, any new sources or major modifications to an existing GHG source causing a net significant increase in carbon dioxide emissions must comply with BACT permit limits for carbon dioxide if it would otherwise be subject to BACT or lowest achievable emissions rate limits due to significant increases in other pollutants.
	In June 2013, President Obama released his Climate Action Plan that reiterates the goal of reducing GHG 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 more restrictive energy efficiency standards. Additionally, the Climate Action Plan calls for the U.S. to prepare for the impacts of climate change. Requirements related to this plan could affect PPL Energy Supply and others in the industry as modifications may be needed to electricity delivery systems to improve the ability to withstand major storms in order to meet those requirements. As further described below, the EPA has proposed rules pursuant to this directive, which it expects to finalize in the second or third quarter of 2015. The EPA has also announced that it will develop a federal implementation plan which would apply to any states that fail to submit an acceptable state implementation plan. The EPA’s authority to promulgate these regulations under Section 111 of the Clean Air Act when the sources are already regulated under Section 112 is under challenge in the D.C. Circuit Court. Oral arguments were heard on April 16, 2015.
	In January 2014, the EPA issued a revised proposal to regulate carbon dioxide emissions from new power plants. The revised proposal calls for 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-fired plants. The standard for natural gas-fired combined-cycle power plants is the same as the EPA proposed in 2012 and is not continuously achievable. The preclusion of new coal-fired plants and the compliance difficulties posed for new gas-fired plants could have a significant industry-wide impact.
	In June 2014, the EPA issued proposed regulations addressing carbon dioxide emissions from existing power plants. The existing plant proposal contains state-specific rate-based reduction goals and guidelines for the development, submission and implementation of state plans to achieve the state goals. State-specific goals were calculated from 2012 data by applying EPA's broad interpretation and definition of the Best System of Emission Reduction resulting in stringent targets to be met in two phases (2020-2029 and 2030 and beyond). The EPA believes it has offered some flexibility to the states as to how state compliance plans can be crafted, including the option to demonstrate compliance on a mass basis and through multi-state collaborations. The EPA is also proposing potential state plan extensions based on the type of plan filed (single or multi-state). PPL has analyzed the proposal and identified potential impacts and solutions in comments filed on December 1, 2014. PPL also submitted Supplemental Comments to FERC through EEI advocating for reliability coordination and relief in response to technical conferences hosted by FERC on the reliability implications of implementing this rule. The regulation of carbon dioxide emissions from existing power plants could have a significant industry-wide impact depending on the structure and stringency of the final rule and state implementation plans.
	In June 2014, the EPA also proposed a regulation addressing carbon dioxide emissions from existing power plants that are modified or reconstructed. PPL Energy Supply, however, does not expect a significant impact from this rulemaking as there are no plans to modify or reconstruct their existing plants in a manner that would trigger the proposed requirements.
	Based on the stringent GHG reduction requirements in the EPA's proposed rule, for existing plants and based on information gained from public input, the PADEP is no longer expecting to achieve all required GHG reductions by solely increasing efficiency at existing fossil-fuel plants and/or reducing their generation as set forth in the PADEP's April 10, 2014 white paper.  In October 2014, the Governor of Pennsylvania signed into law, Act 175 of 2014 requiring the PADEP to obtain General Assembly approval of any state plan addressing GHG emissions under the EPA's GHG rules for existing plants.  The law includes provisions to minimize the exposure to a federal implementation plan due to legislative delay.
	The MDEQ, at the request of the Governor of Montana, has issued a white paper outlining possible regulatory scenarios to implement the EPA's proposed GHG rule for existing plants including a combination of increasing energy efficiency at coal-fired plants, adding more low- and zero-carbon generation, and carbon sequestration at Colstrip.  The white paper was made public in September 2014 and the MDEQ has held public meetings to present the white paper and gather comments. Legislation drafted to require legislative approval of any related plan formulated by MDEQ was tabled.
	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.  PPL Energy Supply cannot predict the outcome of these lawsuits or estimate a range of reasonably possible losses, if any.
	Renewable Energy Legislation
	In Pennsylvania, House Bill 100 was introduced in February 2015, proposing to increase AEPS solar and Tier 1 targets. A similar bill is in the process of being introduced in the Senate (no bill number is available at this time). PPL Energy Supply cannot predict the outcome of this legislative effort.
	In New Jersey, a bill (S-1475) has been introduced to increase the current Renewable Portfolio Standard (RPS) to 30% from Class I sources by 2020.  The chairman of the Senate Environmental Committee convened a workgroup to look at further changes to New Jersey's RPS law to enable New Jersey to meet emissions goals established in the state's Global Warming Response Act.  A bill (S-2444) was subsequently introduced to mandate that 80% of New Jersey's electricity be generated from renewable resources by 2050.  PPL Energy Supply cannot predict the outcome of this legislation.
	PPL Energy Supply believes there are financial, regulatory and operational 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 Energy Supply cannot predict 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)
On April 17, 2015, the EPA published its final rule regulating CCRs. CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes. The rule will become effective on October 14, 2015. It imposes extensive new requirements, including location restrictions, design and operating standards, groundwater monitoring and corrective action requirements and closure and post-closure care requirements on CCR impoundments and landfills that are located on active power plants and not closed. Under the rule, the EPA will regulate CCRs as non-hazardous under Subtitle D of RCRA and allow beneficial use of CCRs, with some restrictions. This self-implementing rule requires posting of compliance documentation on a publicly accessible website and is enforceable through citizen suits. PPL Energy Supply expects that its plants using surface impoundments for management and disposal of CCRs or the past management of CCRs and continued use to manage waste waters will be most impacted by this rule. The rule's requirements for covered CCR impoundments and landfills include commencement or completion of closure activities generally between three and ten years from certain triggering events. PPL Energy Supply also anticipates incurring capital or operation and maintenance costs prior to that time to address other provisions of the rule, such as groundwater monitoring and disposal facility modifications, or to implement various compliance strategies.
PPL Energy Supply is reviewing the rule and is still evaluating its financial and operational impact. It is expected that these requirements will result in increases to existing AROs which will be recorded in the second quarter of 2015. PPL Energy Supply is not yet able to determine an estimate of the expected increases to the existing AROs.
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 as proposed. The proposal contains alternative approaches, some of which could significantly impact PPL Energy Supply's coal-fired plants.  The final regulation is expected to be issued by the third or fourth quarter of 2015. At the present time, PPL Energy Supply is 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 (including Pennsylvania) and environmental groups 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.
Seepages and Groundwater Infiltration - Pennsylvania and Montana
Seepages or groundwater infiltration have been detected at active and retired wastewater basins and landfills at various PPL Energy Supply plants.  PPL Energy Supply has completed or is completing assessments of seepages or groundwater infiltration at various facilities and has completed or is working with agencies to respond to notices of violations and implement assessment or abatement measures, where required or applicable.  A range of reasonably possible losses cannot currently be estimated.
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 this facility.
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.  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.  This matter was stayed in December 2012.  In April 2014, Earthjustice filed a motion for leave to amend the petition for review and to lift the stay which was granted by the court in May 2014.  PPL Montana and the MDEQ responded to the amended petition and filed partial motions to dismiss in July 2014, which were both denied in October 2014. Discovery is ongoing, and a bench trial is set for April 2016.
Clean Water Act/316(b)
The EPA's final 316(b) rule for existing facilities, became effective in October 2014, and regulates cooling water intake structures and their impact on aquatic organisms.  States are allowed considerable authority to make site-specific determinations under the rule.  The rule requires existing facilities to choose between several options to reduce the impact to aquatic organisms that become trapped against water intake screens (impingement) and to determine the intake structure's impact on aquatic organisms pulled through a plant's cooling water system (entrainment).  Plants already equipped with closed-cycle cooling, an acceptable option, would likely not incur substantial costs.  Once-through systems would likely require additional technology to comply with the rule.  Brunner Island (all units) are the only units expected to be impacted.
PPL Energy Supply is evaluating compliance strategies but does not presently expect the compliance costs to be material.
Waters of the United States (WOTUS)
In April 2014, the EPA and the U.S. Army Corps of Engineers (Army Corps) published a proposed rule defining WOTUS that could greatly expand the federal government's interpretation of what constitutes WOTUS subject to regulation under the Clean Water Act.  If the definition is expanded as proposed by the EPA and the Army Corps, permits and other regulatory requirements may be imposed for many matters presently not covered (including vegetation management for transmission lines and activities affecting storm water conveyances and wetlands), the implications of which could be significant. The EPA plans to make certain changes to the proposed regulation based on comments received. The U.S. House and Senate are considering legislation to block this regulation. Until a final rule is issued, PPL Energy Supply cannot predict the outcome of the pending rulemaking. A final rule is expected by summer 2015.
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 2015.  PCBs are found, in varying degrees, in all of PPL Energy Supply's operations.  PPL Energy Supply cannot predict at this time the outcome of these proposed EPA regulations and what impact, if any, they would have on its facilities, but the costs could be significant.
A subsidiary of PPL Energy Supply has investigated alternatives to exclude fish from the discharge channel at its Brunner Island plant.  In June 2012, a Consent Order and Agreement (COA) with the PADEP was signed, allowing the subsidiary to study a change in a cooling tower operational method that may keep fish from entering the channel.  The COA required a retrofit of impingement control technology at the intakes to the cooling towers, at a cost that would have been significant.  Based on the results of the first year of study, the PADEP has suggested closing the COA and writing a new COA to resolve the issue.  PPL Energy Supply is in negotiations with the agency at this time.  PPL Energy Supply cannot predict at this time the outcome of the proposed new COA and what impact, if any, it would have on their facilities, but the costs could be significant.
Superfund and Other Remediation
From time to time, PPL Energy Supply undertakes remedial action in response to notices of violations, spills or other releases at various on-site and off-site locations, negotiate with the EPA and state and local agencies regarding actions necessary for compliance with applicable requirements, negotiate with property owners and other third parties alleging impacts from PPL Energy Supply's operations and undertake similar actions necessary to resolve environmental matters that 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 PPL Energy Supply's operations.
Future cleanup or remediation work at sites currently under review, or at sites not currently identified, may result in significant additional costs for PPL Energy Supply.
Other
Nuclear Insurance
The Price-Anderson Act is a United States Federal law governing liability-related issues and ensures the availability of funds for public liability claims arising from an incident at any U.S. licensed nuclear facility.  It also seeks to limit the liability of nuclear reactor owners for such claims from any single incident.  At March 31, 2015, the liability limit per incident is $13.6 billion for such claims which is funded by insurance coverage from American Nuclear Insurers 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.  At March 31, 2015, facilities at the Susquehanna plant are insured against property damage losses up to $2.0 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.  This maximum assessment is $46 million at March 31, 2015. Effective April 1, 2015, this maximum assessment increased to $55 million. PPL Energy Supply has additional coverage that, under certain conditions, may reduce this exposure.
Guarantees and Other Assurances
In the normal course of business, PPL Energy Supply enters 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.
The table below details guarantees provided as of March 31, 2015.  "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 for the guarantees described below is remote with the exception of a $12 million recorded liability at March 31, 2015. The recorded liability at December 31, 2014 was $13 million.
	Exposure at		Expiration
	March 31, 2015		Date
Indemnifications for sales of assets	1,150	(a)	2016 - 2025
(a)	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. The exposure at March 31, 2015 includes amounts related to the sale of the Montana Hydroelectric facilities. See Note 5 for additional information related to the sale.
PPL Energy Supply provides 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 (including PPL Energy Supply), 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	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions
	PLR Contracts/Purchase of Accounts Receivable
	PPL Electric holds competitive solicitations for PLR generation supply.  PPL EnergyPlus has been awarded a portion of the PLR generation supply through these competitive solicitations.  The sales between PPL EnergyPlus and PPL Electric are included in the Statements of Income as "Unregulated wholesale energy to affiliate" by PPL Energy Supply.
	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 when:  (a) 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.  At March 31, 2015, PPL EnergyPlus was not required to post collateral.
	PPL Electric's customers may choose an alternative supplier for their generation supply.  See Note 2 for additional information regarding PPL Electric's purchases of accounts receivable from PPL EnergyPlus.
	At March 31, 2015, PPL EnergyPlus had a net credit exposure of $31 million from PPL Electric from its commitment as a PLR supplier and from the sale of its accounts receivable to PPL Electric.
	Support Costs
	PPL Energy Supply is provided with administrative, management and support services, primarily from PPL Services. Where applicable, the costs of these services are charged to PPL Energy Supply as direct support costs.  General costs that cannot be directly attributed to a specific affiliate are allocated and charged to the respective affiliates, including PPL Energy Supply, as indirect support costs.  PPL Services uses a three-factor methodology that includes the affiliates invested capital, operation and maintenance expenses and number of employees to allocate indirect costs.
	PPL Energy Supply was charged primarily by PPL Services the following amounts for the periods ended March 31, and believes these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
		Three Months
		2015		2014
		$	49	$	58
	Other
	See Note 6 for discussions regarding intercompany allocations associated with defined benefits.

Other_Income_Expense_net

Other Income (Expense) - net	3 Months Ended
	Mar. 31, 2015
Other Nonoperating Income (Expense) [Abstract]
Other Income (Expense) - net	Other Income (Expense) - net
	"Other Income (Expense) - net" for the three months ended March 31, 2015 and 2014 was primarily earnings on securities in NDT funds.

Fair_Value_Measurements_and_Cr

Fair Value Measurements and Credit Concentration	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements and Credit Concentration	Fair Value Measurements and Credit Concentration
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price).  A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models), and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate.  These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability.  These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk.  The fair value of a group of financial assets and liabilities is measured on a net basis.  Transfers between levels are recognized at end-of-reporting-period values.  During the three months ended March 31, 2015 and 2014, there were no transfers between Level 1 and Level 2.  See Note 1 in PPL Energy Supply's 2014 Form 10-K for information on the levels in the fair value hierarchy.
	Recurring Fair Value Measurements
	The assets and liabilities measured at fair value were:
		31-Mar-15															31-Dec-14
		Total			Level 1				Level 2				Level 3				Total			Level 1			Level 2		Level 3
	Assets
	Cash and cash equivalents	$	221		$	221			$	—			$	—			$	352		$	352		$	—	$	—
	Restricted cash and cash equivalents (a)	201			201				—				—				193			193			—		—
	Price risk management assets:
	Energy commodities	1,298			2				1,136				160				1,318			6			1,171		141
	Total price risk management assets	1,298			2				1,136				160				1,318			6			1,171		141
	NDT funds:
	Cash and cash equivalents	20			20				—				—				19			19			—		—
	Equity securities
	U.S. large-cap	620			461				159				—				611			454			157		—
	U.S. mid/small-cap	93			38				55				—				89			37			52		—
	Debt securities
	U.S. Treasury	97			97				—				—				99			99			—		—
	U.S. government sponsored agency	8			—				8				—				9			—			9		—
	Municipality	76			—				76				—				76			—			76		—
	Investment-grade corporate	45			—				45				—				42			—			42		—
	Other	3			—				3				—				3			—			3		—
	Receivables (payables), net	3			1				2				—				2			—			2		—
	Total NDT funds	965			617				348				—				950			609			341		—
	Auction rate securities (b)	8			—				—				8				8			—			—		8
	Total assets	$	2,693		$	1,041			$	1,484			$	168			$	2,821		$	1,160		$	1,512	$	149
	Liabilities
	Price risk management liabilities:
	Energy commodities	$	1,163		$	2			$	1,130			$	31			$	1,217		$	5		$	1,182	$	30
	Total price risk management liabilities	$	1,163		$	2			$	1,130			$	31			$	1,217		$	5		$	1,182	$	30
	(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.
	A reconciliation of net assets and liabilities classified as Level 3 for the periods ended March 31, is as follows:
		Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
		Three Months 2015
		Energy Commodities, net			Auction Rate Securities				Total
	Balance at beginning of period	$	111		$	8			$	119
	Total realized/unrealized gains (losses) included in earnings	(17		)	—				(17		)
	Settlements	30			—				30
	Transfers into Level 3	4			—				4
	Transfers out of Level 3	1			—				1
	Balance at end of period	$	129		$	8			$	137
		Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
		Three Months 2014
		Energy Commodities, net			Auction Rate Securities				Total
	Balance at beginning of period	$	24		$	16			$	40
	Total realized/unrealized gains (losses) included in earnings	(135		)	—				(135		)
	Sales	—			(3		)		(3		)
	Settlements	128			—				128
	Balance at end of period	$	17		$	13			$	30
	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:
		31-Mar-15
		Fair Value, net			Valuation		Significant Unobservable		Range
		Asset			Technique		Input(s)		(Weighted
		(Liability)							Average) (a)
	Energy commodities
	Natural gas contracts (b)	$	49		Discounted cash flow		Proprietary model used to calculate forward prices		11% - 100% (43%)
	Power sales contracts (c)	1			Discounted cash flow		Proprietary model used to calculate forward prices		10% - 100% (82%)
	Heat rate options (e)	79			Discounted cash flow		Proprietary model used to calculate forward prices		22% - 44% (40%)
	Auction rate securities (f)	8			Discounted cash flow		Modeled from SIFMA Index		50% - 69% (56%)
		December 31, 2014
		Fair Value, net			Valuation		Significant Unobservable		Range
		Asset			Technique		Input(s)		(Weighted
(Liability)					Average) (a)
Energy commodities
Natural gas contracts (b)	$	59		Discounted cash flow		Proprietary model used to calculate forward prices		11% - 100% (52%)
Power sales contracts (c)	(1		)	Discounted cash flow		Proprietary model used to calculate forward prices		10% - 100% (59%)
FTR purchase contracts (d)	3			Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
Heat rate options (e)	50			Discounted cash flow		Proprietary model used to calculate forward prices		23% - 51% (45%)
Auction rate securities (f)	8			Discounted cash flow		Modeled from SIFMA Index		51% - 69% (63%)
(a)	For energy commodities and auction rate securities, the range and weighted average represent the percentage of fair value derived from the unobservable inputs.
(b)	As the forward price of natural gas increases/(decreases), the fair value of purchase contracts increases/(decreases).  As the forward price of natural gas increases/(decreases), the fair value of sales contracts (decreases)/increases.
(c)	As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases.  As volumetric assumptions for contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases).  As volumetric assumptions for contracts in a loss position increase/(decrease), the fair value of the contracts (decreases)/increases.
(d)	As the forward implied spread increases/(decreases), the fair value of the contracts increases/(decreases).
(e)	The proprietary model used to calculate fair value incorporates market heat rates, correlations and volatilities.  As the market implied heat rate increases/(decreases), the fair value of the 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).
Net gains and losses on assets and liabilities classified as Level 3 and included in earnings for the periods ended March 31 are reported in the Statements of Income as follows:
		Three Months
		Energy Commodities, net
		Unregulated							Unregulated								Energy Purchases
		Wholesale Energy							Retail Energy
		2015			2014				2015				2014				2015			2014
Total gains (losses) included in earnings		$	21		$	(89	)		$	(40	)		$	(63	)		$	2		$	17
Change in unrealized gains (losses) relating		25			(13		)		(9		)		(33		)		1			1
to positions still held at the reporting date
Price Risk Management Assets/Liabilities - Energy Commodities
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.  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 other standard industry models.  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.
When unobservable inputs are significant to the fair value measurement, a contract is classified as Level 3.  Level 3 contracts are valued using PPL Energy Supply's 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, volumetric assumptions, implied volatilities, implied correlations, and market implied heat rates.  Forward transactions, including forward transactions classified as Level 3, are analyzed by PPL Energy Supply's Risk Management department.  Accounting personnel 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 Energy Supply's own creditworthiness (for net liabilities) and its counterparties' creditworthiness (for net assets).  PPL Energy Supply'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 2015 were changes in the availability of market information and changes in the significance of the unobservable inputs utilized in the valuation of the contracts.
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, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments.  When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as payment data, future predicted cash flows, collateral performance and new issue data.
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.
Auction rate securities are valued by PPL Energy Supply's Treasury department.  Accounting personnel interpret the analysis quarterly to classify the contracts in the fair value hierarchy.  Valuation techniques are evaluated periodically.
Nonrecurring Fair Value Measurements
The following nonrecurring fair value measurement occurred during the three months ended March 31, 2014, resulting in an asset impairment:
	Carrying			Fair Value Measurements Using				Loss (b)
	Amount (a)			Level 3
Kerr Dam Project:
31-Mar-14	$	47		$	29			$	18
(a)	Represents carrying value before fair value measurement.
(b)	The loss on the Kerr Dam Project is included in "Income (Loss) from Discontinued Operations (net of income taxes)" on the 2014 Statement of Income.
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			Valuation		Significant		Range
		Asset			Technique		Unobservable		(Weighted
		(Liability)					Input(s)		Average)(a)
	Kerr Dam Project:
	31-Mar-14	$	29		Discounted cash flow		Proprietary model used to calculate plant value		38% (38%)
(a)	The range and weighted average represent the percentage of fair value derived from the unobservable inputs.
Kerr Dam Project
PPL Montana previously held a joint operating license issued for the Kerr Dam Project.  The license extends until 2035 and, between 2015 and 2025, the Confederated Salish and Kootenai Tribes of the Flathead Nation (the Tribes) have the option to purchase, hold and operate the Kerr Dam Project.  The parties submitted the issue of the appropriate amount of the conveyance price to arbitration in February 2013.  In March 2014, the arbitration panel issued its final decision holding that the conveyance price payable by the Tribes for the Kerr Dam Project is $18 million.  As a result of the decision, PPL Energy Supply performed a recoverability test on the Kerr Dam Project and recorded an impairment charge.  PPL Energy Supply performed an internal analysis using an income approach based on discounted cash flows (a PPL Energy Supply proprietary model) to assess the fair value of the Kerr Dam Project.  Assumptions used in the PPL Energy Supply proprietary model were the conveyance price, forward energy price curves, forecasted generation, and forecasted operation and maintenance expenditures that were consistent with assumptions used in the business planning process and a market participant discount rate.  Through this analysis, PPL Energy Supply determined the fair value of the Kerr Dam Project to be $29 million at March 31, 2014. The Kerr Dam Project was included in the sale of the Montana Hydroelectric facilities and the assets were removed from the Balance Sheet. See Note 5 for additional information on the sale of the Montana Hydroelectric facilities.
The assets were valued by the PPL Energy Supply Financial Department.  Accounting personnel interpreted the analysis to appropriately classify the assets in the fair value hierarchy.
Financial Instruments Not Recorded at Fair Value
The carrying amounts of long-term debt on the Balance Sheets and its estimated fair values are set forth below.  The fair value was estimated using an income approach by discounting future cash flows at estimated current cost of funding rates, which incorporates the credit risk of PPL Energy Supply.  Long-term debt is classified as Level 2.
	31-Mar-15							31-Dec-14
	Carrying Amount			Fair Value				Carrying Amount				Fair Value
Long-term debt	$	2,217		$	2,221			$	2,218			$	2,204
The carrying value of short-term debt, 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
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 11 for information on credit policies used to manage credit risk, including master netting arrangements and collateral requirements.
At March 31, 2015, PPL Energy Supply had credit exposure of $692 million 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, PPL Energy Supply's credit exposure was reduced to $402 million.  The top ten counterparties including their affiliates accounted for $220 million, or 55%, of these exposures.  Eight of these counterparties had an investment grade credit rating from S&P or Moody's and accounted for 75% of the top ten exposures.  The remaining counterparties are rated below investment grade, but are current on their obligations. See Note 8 for information regarding PPL Energy Supply's related party credit exposure.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities
	Risk Management Objectives
	PPL Energy Supply has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances and foreign exchange (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk).  The 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 and interest 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.
	PPL Energy Supply is subject to market risks, which are actively mitigated through the risk management program described above. Such risks include:
	•	Commodity price risk, including basis and volumetric risk
	•	Interest rate risk
	•	Equity securities price risk
	Commodity price risk
	•	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.
	Interest rate risk
	•	PPL Energy Supply and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances.
	•	PPL Energy Supply and its subsidiaries are exposed to interest rate risk associated with debt securities held by defined benefit plans.  Additionally, PPL Energy Supply is exposed to interest rate risk associated with debt securities held by the NDT.
	Equity securities price risk
	•	PPL Energy Supply and its subsidiaries are exposed to equity securities price risk associated with defined benefit plans.  Additionally, PPL Energy Supply is exposed to equity securities price risk in the NDT funds.
	Credit Risk
	Credit risk is the potential loss that may be incurred due to a counterparty's non-performance.
	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.
	The majority of 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.
	PPL Energy Supply has 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 Energy Supply 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 10 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 Energy Supply's obligation to return counterparty cash collateral under master netting arrangements was $11 million at March 31, 2015 and December 31, 2014.
	PPL Energy Supply did not post any cash collateral under master netting arrangements at March 31, 2015 and December 31, 2014.
	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.
	Commodity Price Risk (Non-trading)
	Commodity price risk, including basis and volumetric risk, is among PPL Energy Supply's most significant risks due to the level of investment that PPL Energy Supply maintains in its 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 6,496 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 3,252 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 Energy Supply enters 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 Energy Supply segregates its 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.  In 2015 and 2014, there were no active cash flow hedges and there was no hedge ineffectiveness associated with energy derivatives.  At March 31, 2015, the accumulated net unrecognized after-tax gains (losses) that are expected to be reclassified into earnings during the next 12 months were $18 million.  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.  There were no such reclassifications for the three months ended March 31, 2015 and 2014.
	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. The derivative contracts in this category that existed at March 31, 2015 range in maturity through 2020.
	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 unrealized gains (losses) for economic activity for the periods ended March 31 were as follows.
		Three Months
		2015				2014
	Operating Revenues
	Unregulated wholesale energy	$	(92	)		$	(789	)
	Unregulated retail energy	(13		)		(26		)
	Operating Expenses
	Fuel	—				(1		)
	Energy purchases	145				580
	Commodity Price Risk (Trading)
	PPL Energy Supply has a proprietary trading strategy which is utilized to take advantage of market opportunities primarily in its geographic footprint.  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 the three months ended March 31, 2015 and 2014.
	Commodity Volumes
	At March 31, 2015, 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		2015 (b)			2016			2017			Thereafter
	Power		MWh		(30,874,062	)		(8,521,382	)		(248,329	)		2,236,333
	Capacity		MW-Month		(3,998	)		(878	)		6			3
	Gas		MMBtu		157,995,389			87,545,701			13,742,416			20,314,625
	FTRs		MW-Month		532			—			—			—
	Oil		Barrels		300,328			387,429			257,483			60,000
	(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.
	(b)	Represents balance of the current year.
	Accounting and Reporting
	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 Energy Supply include certain full-requirement sales contracts, other physical purchase and sales contracts and certain retail energy and physical capacity 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. PPL Energy Supply has many physical and financial commodity purchases and sales contracts that economically hedge commodity price risk but do not receive hedge accounting treatment.  As such, realized and unrealized gains (losses) on these contracts are recorded currently in earnings.  Generally each contract is considered a unit of account and PPL Energy Supply presents gains (losses) on physical and financial commodity sales contracts in "Unregulated wholesale energy" or "Unregulated retail energy" and (gains) losses on physical and financial commodity purchase contracts in "Fuel" or "Energy purchases" on the Statements of Income.  Certain of the economic hedging strategies employed by PPL Energy Supply utilize a combination of financial purchases and sales contracts which are similarly reported gross as an expense and revenue, respectively, on the Statements of Income.  PPL Energy Supply records realized hourly net sales or purchases of physical power with PJM in its Statements of Income as "Unregulated wholesale energy" if in a net sales position and "Energy purchases" if in a net purchase position.
	See Notes 1 and 17 in PPL Energy Supply's 2014 Form 10-K for additional information on accounting policies related to derivative instruments.
	The following table presents the fair value and location of derivative instruments not designated as hedging instruments recorded on the Balance Sheets.
			31-Mar-15								31-Dec-14
			Assets				Liabilities				Assets				Liabilities
Current:
Price Risk Management Assets/Liabilities (a):
Commodity contracts		$	988			$	904			$	1,079			$	1,024
Noncurrent:
Price Risk Management Assets/Liabilities (a):
Commodity contracts		310				259				239				193
Total derivatives		$	1,298			$	1,163			$	1,318			$	1,217
(a)	Represents the location on the Balance Sheets.
The following tables present the pre-tax effect of derivative instruments recognized in income or OCI for the period ended March 31, 2015.
								Three Months
		Derivative Gain				Location of Gains (Losses) Recognized in Income on Derivative		Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
		(Loss) Recognized in
		OCI (Effective Portion)
Derivative		Three Months
Relationships
Cash Flow Hedges:
Commodity contracts		$	—			Unregulated wholesale energy		$	(2	)		$	—
						Energy purchases		8				—
						Depreciation		1				—
Total		$	—					$	7			$	—
Derivatives Not Designated as		Location of Gain (Loss) Recognized in		Three Months
Hedging Instruments		Income on Derivative
Commodity contracts		Unregulated wholesale energy		$	(229	)
		Unregulated retail energy		(39		)
		Fuel		(3		)
		Energy purchases		196
		Total		$	(75	)
The following tables present the pre-tax effect of derivative instruments recognized in income or OCI for the period ended March 31, 2014.
								Three Months
		Derivative Gain				Location of Gains (Losses) Recognized in Income on Derivative		Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
		(Loss) Recognized in
		OCI (Effective Portion)
Derivative		Three Months
Relationships
Cash Flow Hedges:
Commodity contracts		$	—			Unregulated wholesale energy		$	(1	)		$	—
						Energy purchases		7				—
						Depreciation		1				—
						Discontinued operations		2				—
Total		$	—					$	9			$	—
Derivatives Not Designated as		Location of Gain (Loss) Recognized in		Three Months
Hedging Instruments		Income on Derivative
Commodity contracts		Unregulated wholesale energy (a)		$	(3,042	)
		Unregulated retail energy		(64		)
		Fuel		(1		)
		Energy purchases (b)		2,364
		Discontinued operations		(2		)
		Total		$	(745	)
(a)	2014 includes significant realized and unrealized losses on physical and financial commodity sales contracts due to the unusually cold weather.
(b)	2014 includes significant realized and unrealized gains on physical and financial commodity purchase contracts due to the unusually cold weather.
Offsetting Derivative Instruments
Certain subsidiaries of PPL Energy Supply 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 a FCM to use and apply any property in its possession as a setoff 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.  Certain subsidiaries of PPL Energy Supply 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 set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation.
PPL Energy Supply has 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 energy commodities derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
				Assets														Liabilities
								Eligible for Offset												Eligible for Offset
				Gross				Derivative				Cash Collateral Received				Net		Gross		Derivative		Cash Collateral Pledged		Net
								Instruments												Instruments
31-Mar-15				$	1,298			$	990			$	11			$	297	$	1,163	$	990	$	49	$	124
31-Dec-14				$	1,318			$	1,060			$	10			$	248	$	1,217	$	1,060	$	58	$	99
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 Energy Supply.  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 credit rating were to fall below investment grade, 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. PPL Energy Supply's credit rating is currently below investment grade.
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 Energy Supply'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 March 31, 2015, derivative contracts in a net liability position that contain credit risk-related contingent features, collateral posted on those positions and the additional collateral requirements, primarily related to further adequate assurance features are summarized as follows:
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features		$	122
Aggregate fair value of collateral posted on these derivative instruments		118
Aggregate fair value of additional collateral requirements, primarily related to further adequate assurance features (a)		32
(a)	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations
	The changes in the carrying amounts of AROs for PPL Energy Supply were as follows.
	Balance at December 31, 2014	$	425
	Accretion expense	8
	Balance at March 31, 2015	$	433
	Substantially all of the ARO balances are classified as noncurrent at March 31, 2015 and December 31, 2014.
	PPL Energy Supply's most significant ARO relates to the decommissioning of the Susquehanna nuclear plant. See Notes 10 and 13 for additional information on the assets in the NDT funds that are legally restricted for the purposes of settling this ARO.
	See Note 7 for information on a CCR rule that is expected to require the recording of additional AROs in the second quarter of 2015.

AvailableforSale_Securities

Available-for-Sale Securities	3 Months Ended
	Mar. 31, 2015
Available-for-sale Securities [Abstract]
Available-for-Sale Securities	Available-for-Sale Securities
	Securities held by the NDT funds and auction rate securities are classified as available-for-sale.  Available-for-sale securities are carried on the Balance Sheets at fair value.  Unrealized gains and losses on these securities are reported, net of tax, in OCI or are recognized currently in earnings when a decline in fair value is determined to be other-than-temporary.  The specific identification method is used to calculate realized gains and losses.
	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.
		31-Mar-15										31-Dec-14
		Amortized			Gross			Gross		Fair Value		Amortized		Gross		Gross		Fair Value
		Cost			Unrealized			Unrealized				Cost		Unrealized		Unrealized
					Gains			Losses						Gains		Losses
	NDT funds:
	Cash and cash equivalents	$	20		$	—		$	—	$	20	$	19	$	—	$	—	$	19
	Equity securities	287			426			—		713		283		417		—		700
	Debt securities	218			12			1		229		218		11		—		229
	Receivables/payables, net	3			—			—		3		2		—		—		2
	Total NDT funds	$	528		$	438		$	1	$	965	$	522	$	428	$	—	$	950
	Auction rate securities	$	8		$	—		$	—	$	8	$	8	$	—	$	—	$	8
	See Note 10 for details on the securities held by the NDT funds.
	There were no securities with credit losses at March 31, 2015 and December 31, 2014.
	The following table shows the scheduled maturity dates of debt securities held at March 31, 2015.
		Maturity			Maturity			Maturity		Maturity		Total
		Less Than			5-Jan			10-Jun		in Excess
		1 Year			Years			Years		of 10 Years
	Amortized cost	$	11		$	82		$	67	$	66	$	226
	Fair value	11			84			70		72		237
	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities for the periods ended March 31.
			Three Months
			2015			2014
	Proceeds from sales of NDT securities (a)		$	38		$	27
	Other proceeds from sales		—			3
	Gross realized gains (b)		5			3
	Gross realized losses (b)		3			1
	(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_Comprehensiv

Accumulated Other Comprehensive Income (Loss)	3 Months Ended
	Mar. 31, 2015
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss)
	The after-tax changes in AOCI by component for the periods ended March 31 were as follows.
		Unrealized gains (losses)								Defined benefit plans
		Available-				Qualifying				Prior			Actuarial			Total
		for-sale				derivatives				service			gain
		securities								costs			(loss)
	31-Dec-14	$	202			$	63			$	7		$	(295	)	$	(23	)
	Amounts arising during the period	5				—				—			—			5
	Reclassifications from AOCI	(1		)		(4		)		—			4			(1		)
	Net OCI during the period	4				(4		)		—			4			4
	31-Mar-15	$	206			$	59			$	7		$	(291	)	$	(19	)
	31-Dec-13	$	173			$	88			$	(4	)	$	(180	)	$	77
	Amounts arising during the period	5				—				—			—			5
	Reclassifications from AOCI	(1		)		(5		)		1			1			(4		)
	Net OCI during the period	4				(5		)		1			1			1
	31-Mar-14	$	177			$	83			$	(3	)	$	(179	)	$	78
	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the period ended March 31.  The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income during the periods; rather, they are included in the computation of net periodic defined benefit costs (credits).  See Note 6 for additional information.
			Three Months								Affected Line Item on the
	Details about AOCI		2015				2014				Statements of Income
	Available-for-sale securities		$	2			$	2			Other Income (Expense) - net
	Total Pre-tax		2				2
	Income Taxes		(1		)		(1		)
	Total After-tax		1				1
	Qualifying derivatives
	Energy commodities		(2		)		(1		)		Unregulated wholesale energy
			8				7				Energy purchases
			—				2				Discontinued operations
			1				1				Other
	Total Pre-tax		7				9
	Income Taxes		(3		)		(4		)
	Total After-tax		4				5
	Defined benefit plans
	Prior service costs		—				(2		)
	Net actuarial loss		(7		)		(2		)
	Total Pre-tax		(7		)		(4		)
	Income Taxes		3				2
	Total After-tax		(4		)		(2		)
	Total reclassifications during the period		$	1			$	4

New_Accounting_Guidance_Pendin

New Accounting Guidance Pending Adoption	3 Months Ended
	Mar. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Guidance Pending Adoption	New Accounting Guidance Pending Adoption
	Accounting for Revenue from Contracts with Customers
	In May 2014, the FASB issued accounting guidance that establishes a comprehensive new model for the recognition of revenue from contracts with customers.  This model is based on the core principle that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.
	For public business entities, this guidance can be applied using either a full retrospective or modified retrospective transition method, beginning in annual reporting periods beginning after December 15, 2016 and interim periods within those years. Early adoption is not permitted.  PPL Energy Supply will adopt this guidance effective January 1, 2017.
	PPL Energy Supply is currently assessing the impact of adopting this guidance, as well as the transition method it will use.
	Reporting Uncertainties about an Entity's Ability to Continue as a Going Concern
	In August 2014, the FASB issued accounting guidance which will require management to assess, for each interim and annual period, whether there are conditions or events that raise substantial doubt about an entity's ability to continue as a going concern.  Substantial doubt about an entity's ability to continue as a going concern exists when relevant conditions and events, considered in the aggregate, indicate that it is probable that the entity will be unable to meet its obligations as they become due within one year after the date the financial statements are issued.
	When management identifies conditions or events that raise substantial doubt about an entity's ability to continue as a going concern, management is required to disclose information that enables users of the financial statements to understand the principal conditions or events that raised substantial doubt about the entity's ability to continue as a going concern and management's evaluation of the significance of those conditions or events.  If substantial doubt about the entity's ability to continue as a going concern has been alleviated as a result of management's plan, the entity should disclose information that allows the users of the financial statements to understand those plans.  If the substantial doubt about the entity's ability to continue as a going concern is not alleviated by management's plans, management's plans to mitigate the conditions or events that gave rise to the substantial doubt about the entity's ability to continue as a going concern should be disclosed, as well as a statement that there is substantial doubt the entity's ability to continue as a going concern within one year after the date the financial statements are issued.
	For all entities, this guidance should be applied prospectively within the annual periods ending after December 15, 2016, and for annual periods and interim periods thereafter.  Early adoption is permitted.
	PPL Energy Supply will adopt this guidance for the annual period ending December 31, 2016. The adoption of this guidance is not expected to have a significant impact on PPL Energy Supply.
	Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or to Equity
	In November 2014, the FASB issued guidance that clarifies how current accounting guidance should be interpreted when evaluating the economic characteristics and risks of a host contract of a hybrid financial instrument issued in the form of a share.  This guidance does not change the current criteria for determining whether separation of an embedded derivative feature from a hybrid financial instrument is required.  Entities are still required to evaluate whether the economic risks of the embedded derivative feature are clearly and closely related to those of the host contract, among other relevant criteria.
	An entity should consider the substantive terms and features of the entire hybrid financial instrument, including the embedded derivative feature being evaluated for bifurcation, in evaluating the nature of the host contract to determine whether the host contract is more akin to a debt instrument or more akin to an equity instrument.  An entity should assess the relative strength of the debt-like and equity-like terms and features when determining how to weight those terms and features.
	For public business entities, this guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015 and should be applied using a modified retrospective method for existing hybrid financial instruments issued in the form of a share as of the beginning of the fiscal year the guidance is adopted.  Early adoption is permitted.  Retrospective application is permitted but not required.
	PPL Energy Supply will adopt this guidance on January 1, 2016.  The adoption of this guidance is not expected to have a significant impact on PPL Energy Supply.
	Income Statement Presentation of Extraordinary and Unusual Items
	In January 2015, the FASB issued accounting guidance that eliminates the concept of extraordinary items, which requires an entity to separately classify, present in the income statement and disclose material events and transactions that are both unusual and occur infrequently. The requirement to report material events or transactions that are unusual or infrequent as a separate component of income from continuing operations has been retained, as has the requirement to separately present the nature and financial effects of each event or transaction in the income statement as a separate component of continuing operations or disclose them within the notes to the financial statements. The scope of these requirements has been expanded to include items that are both unusual and occur infrequently.
	This guidance is effective for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted provided that an entity applies the guidance from the beginning of the fiscal year of adoption. The guidance may be applied either retrospectively or prospectively.
	PPL Energy Supply will adopt this guidance on January 1, 2016. The adoption of this guidance is not expected to have a significant impact on PPL Energy Supply.
	Simplifying the Presentation of Debt Issuance Costs
	In April 2015, the FASB issued accounting guidance to simplify the presentation of debt issuance costs by requiring debt issuance costs to be presented on the balance sheet as a direct deduction from the carrying amount of the associated debt liability, consistent with the presentation of debt discounts.
	For public business entities, this guidance should be applied retrospectively for financial statements issued for fiscal years beginning after December 15, 2015 and interim periods within those fiscal years. Early adoption is permitted.
	PPL Energy Supply is assessing in which period it will adopt this new guidance. The adoption of this guidance will require PPL Energy Supply to reclassify debt issuance costs from assets to long-term debt, and is not expected to have a significant impact on PPL Energy Supply.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Accounts Receivable	Accounts Receivable
	In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers (including PPL EnergyPlus) at a discount, which reflects a provision for uncollectible accounts.  PPL EnergyPlus has no continuing involvement or interest in its accounts receivable purchased by PPL Electric.
New Accounting Guidance Adopted	New Accounting Guidance Adopted
	Reporting of Discontinued Operations
	Effective January 1, 2015, PPL Energy Supply prospectively adopted accounting guidance that changes the criteria for determining what should be classified as a discontinued operation and the related presentation and disclosure requirements. A discontinued operation may include a component of an entity or a group of components of an entity, or a business activity. A disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has (or will have) a major effect on the entity's operations and financial results when any of the following occurs: (1) The components of an entity or a group of components of an entity meets the criteria to be classified as held for sale, (2) The component of an entity or a group of components of an entity is disposed of by sale, or (3) The component of an entity or a group of components of an entity is disposed of other than by sale (for example, by abandonment or in a distribution to owners in a spinoff).
	The initial adoption of this guidance did not have a significant impact on PPL Energy Supply but will impact the amounts presented as discontinued operations and will enhance the related disclosure requirements related to future disposals or held for sale classifications.

Acquisitions_Development_and_D1

Acquisitions, Development and Divestitures (Policies)	3 Months Ended
	Mar. 31, 2015
Acquisitions Development And Divestitures [Abstract]
Interest expense allocated to discontinued operations	Represents allocated interest expense based upon the discontinued operations share of the net assets of PPL Energy Supply.

Fair_Value_Measurements_and_Cr1

Fair Value Measurements and Credit Concentration (Policies)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Transfer	Transfers between levels are recognized at end-of-reporting-period values.

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Policies)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Master Netting Agreements	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

AvailableforSale_Securities_Po

Available-for-Sale Securities (Policies)	3 Months Ended
	Mar. 31, 2015
Available-for-sale Securities [Abstract]
Investments	Securities held by the NDT funds and auction rate securities are classified as available-for-sale.  Available-for-sale securities are carried on the Balance Sheets at fair value.  Unrealized gains and losses on these securities are reported, net of tax, in OCI or are recognized currently in earnings when a decline in fair value is determined to be other-than-temporary.  The specific identification method is used to calculate realized gains and losses.

Income_Taxes_Tables

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Reconciliation of income taxes	Reconciliation of income taxes for the periods ended March 31 are:
		Three Months
		2015			2014
	Federal income tax on Income from Continuing Operations Before Income Taxes at statutory tax rate - 35%	$	52		$	(37	)
	Increase (decrease) due to:
	State income taxes, net of federal income tax benefit	5			(12		)
	Federal income tax credits	(3		)	(1		)
	Other	(1		)	3
	Total increase (decrease)	1			(10		)
	Total income taxes	$	53		$	(47	)

Financing_Activities_Tables

Financing Activities (Tables)

3 Months Ended

Mar. 31, 2015

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

The following syndicated credit facility was in place at:

31-Mar-15

31-Dec-14

Expiration

Capacity

Borrowed

Letters of

Unused

Borrowed

Letters of

Date

Credit

Capacity

Credit Issued

Issued

Syndicated Credit Facility (a)

Nov-17

$

3,000

$

600

$

267

$

2,133

$

630

$

121

(a)

At March 31, 2015 and December 31, 2014, interest rates on outstanding borrowings were 2.12% and 2.05%. The amounts borrowed are recorded as "Short-term debt" on the Balance Sheets.

Acquisitions_Development_and_D2

Acquisitions, Development and Divestitures (Tables)	3 Months Ended
	Mar. 31, 2015
Acquisitions Development And Divestitures [Abstract]
Schedule of Components of Discontinued Operations	Following are the components of Discontinued Operations in the Statement of Income for the period ended March 31.
		Three Months
		2014
	Operating revenues	29
	Interest expense (a)	2
	Income (loss) before income taxes (b)	(10	)
	Income (Loss) from Discontinued Operations (net of income taxes) (b)	(8	)
	(a)	Represents allocated interest expense based upon the discontinued operations share of the net assets of PPL Energy Supply.
	(b)	Includes an impairment charge related to the Kerr Dam Project. See Note 10 for additional information.

Defined_Benefits_Tables

Defined Benefits (Tables)	3 Months Ended
	Mar. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL Energy Supply for the periods ended March 31:
		Pension Benefits
		Three Months
		2015			2014
	Service cost	$	1		$	1
	Interest cost	2			2
	Expected return on plan assets	(3		)	(2		)
	Amortization of:
	Actuarial (gain) loss	1			—
	Net periodic defined benefit costs (credits)	$	1		$	1
Allocation of Net Periodic Benefit Costs	For the periods ended March 31, Energy Supply was allocated the following net periodic defined benefit costs.
		Three Months
		2015			2014
		$	11		$	7

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Guarantees	The table below details guarantees provided as of March 31, 2015.  "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 for the guarantees described below is remote with the exception of a $12 million recorded liability at March 31, 2015. The recorded liability at December 31, 2014 was $13 million.
		Exposure at		Expiration
		March 31, 2015		Date
	Indemnifications for sales of assets	1,150	(a)	2016 - 2025
	(a)	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. The exposure at March 31, 2015 includes amounts related to the sale of the Montana Hydroelectric facilities. See Note 5 for additional information related to the sale.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Intercompany Support Cost Allocations	PPL Energy Supply was charged primarily by PPL Services the following amounts for the periods ended March 31, and believes these amounts are reasonable, including amounts applied to accounts that are further distributed between capital and expense.
		Three Months
		2015		2014
		$	49	$	58

Fair_Value_Measurements_and_Cr2

Fair Value Measurements and Credit Concentration (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value of Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were:
		31-Mar-15															31-Dec-14
		Total			Level 1				Level 2				Level 3				Total			Level 1			Level 2		Level 3
	Assets
	Cash and cash equivalents	$	221		$	221			$	—			$	—			$	352		$	352		$	—	$	—
	Restricted cash and cash equivalents (a)	201			201				—				—				193			193			—		—
	Price risk management assets:
	Energy commodities	1,298			2				1,136				160				1,318			6			1,171		141
	Total price risk management assets	1,298			2				1,136				160				1,318			6			1,171		141
	NDT funds:
	Cash and cash equivalents	20			20				—				—				19			19			—		—
	Equity securities
	U.S. large-cap	620			461				159				—				611			454			157		—
	U.S. mid/small-cap	93			38				55				—				89			37			52		—
	Debt securities
	U.S. Treasury	97			97				—				—				99			99			—		—
	U.S. government sponsored agency	8			—				8				—				9			—			9		—
	Municipality	76			—				76				—				76			—			76		—
	Investment-grade corporate	45			—				45				—				42			—			42		—
	Other	3			—				3				—				3			—			3		—
	Receivables (payables), net	3			1				2				—				2			—			2		—
	Total NDT funds	965			617				348				—				950			609			341		—
	Auction rate securities (b)	8			—				—				8				8			—			—		8
	Total assets	$	2,693		$	1,041			$	1,484			$	168			$	2,821		$	1,160		$	1,512	$	149
	Liabilities
	Price risk management liabilities:
	Energy commodities	$	1,163		$	2			$	1,130			$	31			$	1,217		$	5		$	1,182	$	30
	Total price risk management liabilities	$	1,163		$	2			$	1,130			$	31			$	1,217		$	5		$	1,182	$	30
	(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.
Reconciliation of Net Assets and Liabilities Classified as Level 3	A reconciliation of net assets and liabilities classified as Level 3 for the periods ended March 31, is as follows:
		Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
		Three Months 2015
		Energy Commodities, net			Auction Rate Securities				Total
	Balance at beginning of period	$	111		$	8			$	119
	Total realized/unrealized gains (losses) included in earnings	(17		)	—				(17		)
	Settlements	30			—				30
	Transfers into Level 3	4			—				4
	Transfers out of Level 3	1			—				1
	Balance at end of period	$	129		$	8			$	137
		Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
		Three Months 2014
		Energy Commodities, net			Auction Rate Securities				Total
	Balance at beginning of period	$	24		$	16			$	40
	Total realized/unrealized gains (losses) included in earnings	(135		)	—				(135		)
	Sales	—			(3		)		(3		)
	Settlements	128			—				128
	Balance at end of period	$	17		$	13			$	30
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:
		31-Mar-15
		Fair Value, net			Valuation		Significant Unobservable		Range
		Asset			Technique		Input(s)		(Weighted
		(Liability)							Average) (a)
	Energy commodities
	Natural gas contracts (b)	$	49		Discounted cash flow		Proprietary model used to calculate forward prices		11% - 100% (43%)
	Power sales contracts (c)	1			Discounted cash flow		Proprietary model used to calculate forward prices		10% - 100% (82%)
	Heat rate options (e)	79			Discounted cash flow		Proprietary model used to calculate forward prices		22% - 44% (40%)
	Auction rate securities (f)	8			Discounted cash flow		Modeled from SIFMA Index		50% - 69% (56%)
		December 31, 2014
		Fair Value, net			Valuation		Significant Unobservable		Range
		Asset			Technique		Input(s)		(Weighted
		(Liability)							Average) (a)
	Energy commodities
	Natural gas contracts (b)	$	59		Discounted cash flow		Proprietary model used to calculate forward prices		11% - 100% (52%)
	Power sales contracts (c)	(1		)	Discounted cash flow		Proprietary model used to calculate forward prices		10% - 100% (59%)
	FTR purchase contracts (d)	3			Discounted cash flow		Historical settled prices used to model forward prices		100% (100%)
	Heat rate options (e)	50			Discounted cash flow		Proprietary model used to calculate forward prices		23% - 51% (45%)
	Auction rate securities (f)	8			Discounted cash flow		Modeled from SIFMA Index		51% - 69% (63%)
	(a)	For energy commodities and auction rate securities, the range and weighted average represent the percentage of fair value derived from the unobservable inputs.
	(b)	As the forward price of natural gas increases/(decreases), the fair value of purchase contracts increases/(decreases).  As the forward price of natural gas increases/(decreases), the fair value of sales contracts (decreases)/increases.
	(c)	As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases.  As volumetric assumptions for contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases).  As volumetric assumptions for contracts in a loss position increase/(decrease), the fair value of the contracts (decreases)/increases.
	(d)	As the forward implied spread increases/(decreases), the fair value of the contracts increases/(decreases).
	(e)	The proprietary model used to calculate fair value incorporates market heat rates, correlations and volatilities.  As the market implied heat rate increases/(decreases), the fair value of the 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).
	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			Valuation		Significant		Range
			Asset			Technique		Unobservable		(Weighted
			(Liability)					Input(s)		Average)(a)
		Kerr Dam Project:
		31-Mar-14	$	29		Discounted cash flow		Proprietary model used to calculate plant value		38% (38%)
	(a)	The range and weighted average represent the percentage of fair value derived from the unobservable inputs.
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 periods ended March 31 are reported in the Statements of Income as follows:
			Three Months
			Energy Commodities, net
			Unregulated							Unregulated								Energy Purchases
			Wholesale Energy							Retail Energy
			2015			2014				2015				2014				2015			2014
	Total gains (losses) included in earnings		$	21		$	(89	)		$	(40	)		$	(63	)		$	2		$	17
	Change in unrealized gains (losses) relating		25			(13		)		(9		)		(33		)		1			1
	to positions still held at the reporting date
Fair Value of Assets and Liabilities Measured on Nonrecurring Basis	The following nonrecurring fair value measurement occurred during the three months ended March 31, 2014, resulting in an asset impairment:
		Carrying			Fair Value Measurements Using				Loss (b)
		Amount (a)			Level 3
	Kerr Dam Project:
	31-Mar-14	$	47		$	29			$	18
	(a)	Represents carrying value before fair value measurement.
	(b)	The loss on the Kerr Dam Project is included in "Income (Loss) from Discontinued Operations (net of income taxes)" on the 2014 Statement of Income.
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
		31-Mar-15							31-Dec-14
		Carrying Amount			Fair Value				Carrying Amount				Fair Value
	Long-term debt	$	2,217		$	2,221			$	2,218			$	2,204

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Price Risk (Non-trading) - Economic Activity - Pre-tax Gains (Losses) Associated with Economic Activity	The unrealized gains (losses) for economic activity for the periods ended March 31 were as follows.
		Three Months
		2015				2014
	Operating Revenues
	Unregulated wholesale energy	$	(92	)		$	(789	)
	Unregulated retail energy	(13		)		(26		)
	Operating Expenses
	Fuel	—				(1		)
	Energy purchases	145				580
Commodity Volumes- Volumes of Derivative (Sales) Purchase Contracts	At March 31, 2015, 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		2015 (b)			2016			2017			Thereafter
	Power		MWh		(30,874,062	)		(8,521,382	)		(248,329	)		2,236,333
	Capacity		MW-Month		(3,998	)		(878	)		6			3
	Gas		MMBtu		157,995,389			87,545,701			13,742,416			20,314,625
	FTRs		MW-Month		532			—			—			—
	Oil		Barrels		300,328			387,429			257,483			60,000
	(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.
	(b)	Represents balance of the current year.
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and location of derivative instruments not designated as hedging instruments recorded on the Balance Sheets.
			31-Mar-15								31-Dec-14
			Assets				Liabilities				Assets				Liabilities
	Current:
	Price Risk Management Assets/Liabilities (a):
	Commodity contracts		$	988			$	904			$	1,079			$	1,024
	Noncurrent:
	Price Risk Management Assets/Liabilities (a):
	Commodity contracts		310				259				239				193
	Total derivatives		$	1,298			$	1,163			$	1,318			$	1,217
	(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 tables present the pre-tax effect of derivative instruments recognized in income or OCI for the period ended March 31, 2015.
									Three Months
			Derivative Gain				Location of Gains (Losses) Recognized in Income on Derivative		Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
			(Loss) Recognized in
			OCI (Effective Portion)
	Derivative		Three Months
	Relationships
	Cash Flow Hedges:
	Commodity contracts		$	—			Unregulated wholesale energy		$	(2	)		$	—
							Energy purchases		8				—
							Depreciation		1				—
	Total		$	—					$	7			$	—
	Derivatives Not Designated as		Location of Gain (Loss) Recognized in		Three Months
	Hedging Instruments		Income on Derivative
	Commodity contracts		Unregulated wholesale energy		$	(229	)
			Unregulated retail energy		(39		)
			Fuel		(3		)
			Energy purchases		196
			Total		$	(75	)
	The following tables present the pre-tax effect of derivative instruments recognized in income or OCI for the period ended March 31, 2014.
									Three Months
			Derivative Gain				Location of Gains (Losses) Recognized in Income on Derivative		Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
			(Loss) Recognized in
			OCI (Effective Portion)
	Derivative		Three Months
	Relationships
	Cash Flow Hedges:
	Commodity contracts		$	—			Unregulated wholesale energy		$	(1	)		$	—
							Energy purchases		7				—
							Depreciation		1				—
							Discontinued operations		2				—
	Total		$	—					$	9			$	—
	Derivatives Not Designated as		Location of Gain (Loss) Recognized in		Three Months
	Hedging Instruments		Income on Derivative
	Commodity contracts		Unregulated wholesale energy (a)		$	(3,042	)
			Unregulated retail energy		(64		)
			Fuel		(1		)
			Energy purchases (b)		2,364
			Discontinued operations		(2		)
			Total		$	(745	)
	(a)	2014 includes significant realized and unrealized losses on physical and financial commodity sales contracts due to the unusually cold weather.
	(b)	2014 includes significant realized and unrealized gains on physical and financial commodity purchase contracts due to the unusually cold weather.
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the energy commodities derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
					Assets														Liabilities
									Eligible for Offset												Eligible for Offset
					Gross				Derivative				Cash Collateral Received				Net		Gross		Derivative		Cash Collateral Pledged		Net
									Instruments												Instruments
	31-Mar-15				$	1,298			$	990			$	11			$	297	$	1,163	$	990	$	49	$	124
	31-Dec-14				$	1,318			$	1,060			$	10			$	248	$	1,217	$	1,060	$	58	$	99
Credit Risk-Related Contingent Features	At March 31, 2015, derivative contracts in a net liability position that contain credit risk-related contingent features, collateral posted on those positions and the additional collateral requirements, primarily related to further adequate assurance features are summarized as follows:
	Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features		$	122
	Aggregate fair value of collateral posted on these derivative instruments		118
	Aggregate fair value of additional collateral requirements, primarily related to further adequate assurance features (a)		32
	(a)	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The changes in the carrying amounts of AROs for PPL Energy Supply were as follows.
	Balance at December 31, 2014	$	425
	Accretion expense	8
	Balance at March 31, 2015	$	433

AvailableforSale_Securities_Ta

Available-for-Sale Securities (Tables)	3 Months Ended
	Mar. 31, 2015
Available-for-sale Securities [Abstract]
Schedule of Available-for-sale Securities Reconciliation	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.
		31-Mar-15										31-Dec-14
		Amortized			Gross			Gross		Fair Value		Amortized		Gross		Gross		Fair Value
		Cost			Unrealized			Unrealized				Cost		Unrealized		Unrealized
					Gains			Losses						Gains		Losses
	NDT funds:
	Cash and cash equivalents	$	20		$	—		$	—	$	20	$	19	$	—	$	—	$	19
	Equity securities	287			426			—		713		283		417		—		700
	Debt securities	218			12			1		229		218		11		—		229
	Receivables/payables, net	3			—			—		3		2		—		—		2
	Total NDT funds	$	528		$	438		$	1	$	965	$	522	$	428	$	—	$	950
	Auction rate securities	$	8		$	—		$	—	$	8	$	8	$	—	$	—	$	8
Investments Classified by Contractual Maturity Date	The following table shows the scheduled maturity dates of debt securities held at March 31, 2015.
		Maturity			Maturity			Maturity		Maturity		Total
		Less Than			5-Jan			10-Jun		in Excess
		1 Year			Years			Years		of 10 Years
	Amortized cost	$	11		$	82		$	67	$	66	$	226
	Fair value	11			84			70		72		237
Schedule of Realized Gain (Loss)	The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities for the periods ended March 31.
			Three Months
			2015			2014
	Proceeds from sales of NDT securities (a)		$	38		$	27
	Other proceeds from sales		—			3
	Gross realized gains (b)		5			3
	Gross realized losses (b)		3			1
	(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 (Loss) (Tables)	3 Months Ended
	Mar. 31, 2015
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Schedule of changes in AOCI by component	The after-tax changes in AOCI by component for the periods ended March 31 were as follows.
		Unrealized gains (losses)								Defined benefit plans
		Available-				Qualifying				Prior			Actuarial			Total
		for-sale				derivatives				service			gain
		securities								costs			(loss)
	31-Dec-14	$	202			$	63			$	7		$	(295	)	$	(23	)
	Amounts arising during the period	5				—				—			—			5
	Reclassifications from AOCI	(1		)		(4		)		—			4			(1		)
	Net OCI during the period	4				(4		)		—			4			4
	31-Mar-15	$	206			$	59			$	7		$	(291	)	$	(19	)
	31-Dec-13	$	173			$	88			$	(4	)	$	(180	)	$	77
	Amounts arising during the period	5				—				—			—			5
	Reclassifications from AOCI	(1		)		(5		)		1			1			(4		)
	Net OCI during the period	4				(5		)		1			1			1
	31-Mar-14	$	177			$	83			$	(3	)	$	(179	)	$	78
Reclassification from AOCI	The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the period ended March 31.  The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income during the periods; rather, they are included in the computation of net periodic defined benefit costs (credits).  See Note 6 for additional information.
			Three Months								Affected Line Item on the
	Details about AOCI		2015				2014				Statements of Income
	Available-for-sale securities		$	2			$	2			Other Income (Expense) - net
	Total Pre-tax		2				2
	Income Taxes		(1		)		(1		)
	Total After-tax		1				1
	Qualifying derivatives
	Energy commodities		(2		)		(1		)		Unregulated wholesale energy
			8				7				Energy purchases
			—				2				Discontinued operations
			1				1				Other
	Total Pre-tax		7				9
	Income Taxes		(3		)		(4		)
	Total After-tax		4				5
	Defined benefit plans
	Prior service costs		—				(2		)
	Net actuarial loss		(7		)		(2		)
	Total Pre-tax		(7		)		(4		)
	Income Taxes		3				2
	Total After-tax		(4		)		(2		)
	Total reclassifications during the period		$	1			$	4

Business_and_Basis_of_Presenta1

Business and Basis of Presentation (Details) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Apr. 29, 2015	Dec. 31, 2014
Restructuring Cost and Reserve [Line Items]
Maximum length of time term after closing to divest an asset group (in months)	within 12 months
Subsequent Event
Restructuring Cost and Reserve [Line Items]
Spinoff expected completion date		1-Jun-15
Spinoff | PPL Energy Supply Spinoff
Restructuring Cost and Reserve [Line Items]
Initial ownership in new company, Talen Energy, by PPL Shareholders	65.00%
Initial percentage ownership in new company, Talen Energy, by Riverstone Holdings, LLC	35.00%
Minimum capacity of revolving credit facility for Talen required at closing under agreement terms	1,000,000,000
Capacity, in total, to be divested in connection with the spinoff	1,300
Number of asset groups that will be divested	1
Number of asset groups proposed to be divested, one of which to be selected	2
Amount of accrued liability for separation benefits	3,000,000		9,000,000
Spinoff | Minimum | PPL Energy Supply Spinoff
Restructuring Cost and Reserve [Line Items]
Additional seperation costs to be recognized at the spinoff closing date	30,000,000
Spinoff | Maximum | PPL Energy Supply Spinoff
Restructuring Cost and Reserve [Line Items]
Additional seperation costs to be recognized at the spinoff closing date	40,000,000

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Details) (PPL EnergyPlus, PPL Electric, Sale of Accounts Receivable, USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
PPL EnergyPlus | PPL Electric | Sale of Accounts Receivable
Related Party Transaction [Line Items]
Purchases of accounts receivable	$93	$105

Income_Taxes_Reconciliation_of

Income Taxes (Reconciliation of Income Tax Expense) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Jun. 30, 2015
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Federal income tax on Income from Continuing Operations Before Income Taxes at statutory tax rate - 35%	$52	($37)
Federal statutory tax rate	35.00%	35.00%
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5	-12
Federal income tax credits	-3	-1
Other	-1	3
Total increase (decrease)	1	-10
Total income tax from continuing operations	53	-47
Scenario, Forecast | IRS | Minimum
Income Tax Contingency [Line Items]
Expected tax benefit to be recorded			7
Scenario, Forecast | IRS | Maximum
Income Tax Contingency [Line Items]
Expected tax benefit to be recorded			$15

Financing_Activities_Credit_Ar

Financing Activities (Credit Arrangements) (Details) (USD $)	3 Months Ended
	Mar. 31, 2015		Dec. 31, 2014
Syndicated Credit Facility
Line of Credit Facility [Line Items]
Expiration Date	6-Nov-17	[1]
Capacity	$3,000,000,000	[1]
Borrowed	600,000,000	[1]	630,000,000	[1]
Letters of Credit Issued	267,000,000	[1]	121,000,000	[1]
Unused Capacity	2,133,000,000	[1]
Interest rate	2.12%		2.05%
Facility Agreement
Line of Credit Facility [Line Items]
Expiration Date	30-Jun-17
Potential maximum Facility Agreement capacity	500,000,000
Secured Trading Facility
Line of Credit Facility [Line Items]
Expiration Date	3-Nov-19
Secured energy marketing and trading facility capacity	800,000,000
Automatic renewal term (in years)	1 year
Secured obligations outstanding	$88,000,000
[1]	t MarchB 31, 2015 and DecemberB 31, 2014, interest rates on outstanding borrowings were 2.12% and 2.05%. The amounts borrowed are recorded as "Short-term debt" on the Balance Sheets.

Acquisitions_Development_and_D3

Acquisitions, Development and Divestitures (Details) (USD $)	3 Months Ended			1 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014		Nov. 30, 2014
				MW
				facility
Divestitures - Montana Hydro Sale Agreement (Numeric) [Abstract]
Income (Loss) from Discontinued Operations (net of income taxes)	$0	($8)
Montana Hydroelectric Generating Facilities
Divestitures - Montana Hydro Sale Agreement (Numeric) [Abstract]
Capacity of facility sold				633
Agreed upon sales price for disposal of hydroelectric facilities owned by PPL Montana				900
Number of hydroelectric facilities owned by PPL Montana to be sold				11
Operating revenues		29
Interest expense		2	[1]
Income (loss) before income taxes		-10	[2]
Income (Loss) from Discontinued Operations (net of income taxes)		($8)	[2]
[1]	Represents allocated interest expense based upon the discontinued operations share of the net assets of PPL Energy Supply.
[2]	Includes an impairment charge related to the Kerr Dam Project. See Note 10 for additional information.

Defined_Benefits_Details

Defined Benefits (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
PPL Services
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	$11	$7
Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1
Interest cost	2	2
Expected return on plan assets	-3	-2
Amortization of:
Actuarial (gain) loss	1	0
Net periodic defined benefit costs (credits)	$1	$1

Commitments_and_Contingencies_1

Commitments and Contingencies (Energy Purchases, Other Commitments, Legal Matters and Regulatory Issues) (Details) (USD $)	3 Months Ended	1 Months Ended
	Mar. 31, 2015	Apr. 30, 2015
	utility	project
	project
	claim
Legal Matters - Sierra Club Litigation (Numeric) [Abstract]
Number of separate claims included in the complaint against PPL Montana	39
Average requested amount, per day per violation, of injuctive relief and civil penalities	$36,000
Amount of civil penalities to be used for beneficial mitigation projects	100,000
Estimated number of post-2000 projects alleged not to be in compliance with the Clean Air Act	40
Number of plant projects that had claims dismissed under alleged Clean Air Act violations	3
Number of plant projects included in a second amended complaint under alleged Clean Air Act violations	8
Regulatory Issues - Maryland Capacity Order (Numeric) [Abstract]
Number electric utilities ordered to enter into long term contracts	3
Regulatory Issues - Pacific Northwest Markets (Numeric) [Abstract]
Settlement amount reached with one of the parties	75,000
Loss Contingency, Damages Sought, Value	23,000,000
Amount for claims remaining unsettled at period end	50,000,000
Regulatory Issues - Electric - Reliability Standards (Numeric) [Abstract]
Maximum per day penalties for reliability violations	$1,000,000
Subsequent Event
Legal Matters - Sierra Club Litigation (Numeric) [Abstract]
Number of plant projects with remaining claims to be pursued by plaintiffs		4

Commitments_and_Contingencies_2

Commitments and Contingencies (Environmental Matter and Other) (Details) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Apr. 17, 2015	Apr. 01, 2015
	company
	phase
Environmental Matters - Domestic - Air - Cross State Air Pollution Rule (Numeric) [Abstract]
Number of phases CSAPR will be implemented	2
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]
Period for compliance with final MACT standards	3 years
Environmental Matters - Domestic - Air - Climate Change (Numeric) [Abstract]
Percentage reduction of greenhouse gas emissions below 2005 levels by 2020	17.00%
Number of electric utility companies affected by a September 2009 U.S. Court of Appeals for the Second Circuit decision	5
Environmental Matters - Domestic - Air - Renewable Energy Legislation (Numeric) [Abstract]
Proposed percentage of New Jersey renewable energy portfolio standard by 2020	30.00%
Proposed percentage of New Jersey renewable energy portfolio standard by 2050	80.00%
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 years
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	2,000,000,000
Maximum assessment for retroactive premiums for nuclear outage insurance coverage	46,000,000
Minimum
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]
Possible period of extension to comply with final mercury and air toxics standards	1 year
Maximum
Environmental Matters - Domestic - Air - Mercury and Air Toxics (Numeric) [Abstract]
Possible period of extension to comply with final mercury and air toxics standards	2 years
Subsequent Event
Environmental Matters - Domestic - Water/Waste - Coal Combustion Residuals (CCRs) [Abstract]
Minimum range in years to complete closure requirements for CCRs under certain events		3 years
Maximum range in years to complete closure requirements for CCRs under certain events		10 years
Other - Nuclear Insurance (Numeric) [Abstract]
Maximum assessment for retroactive premiums for nuclear outage insurance coverage			$55,000,000

Commitments_and_Contingencies_3

Commitments and Contingencies (Guarantees and Other Assurances) (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
Guarantor Obligations [Line Items]
Recorded liability for all guarantees	$12,000,000		$13,000,000
Maximum aggregate coverage bodily injury and property damage	225,000,000
Indemnification Agreement | Indemnifications for sales of assets
Guarantor Obligations [Line Items]
Maximum exposure	$1,150,000,000	[1]
[1]	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. The exposure at March 31, 2015 includes amounts related to the sale of the Montana Hydroelectric facilities. See Note 5 for additional information related to the sale.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
PPL Services
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	$49	$58
PPL EnergyPlus | PPL Electric
PLR Contracts/Purchase of Accounts Receivable (Numeric) [Abstract]
Credit exposure with affiliate under a Master Supply Agreement	$31

Fair_Value_Measurements_and_Cr3

Fair Value Measurements and Credit Concentration (Assets and Liabilities Measured on Recurring Basis Table) (Details) (Recurring, USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Assets
Cash and cash equivalents	$221		$352
Restricted cash and cash equivalents	201	[1]	193	[1]
Price risk management assets:
Energy commodities assets	1,298		1,318
Total price risk management assets	1,298		1,318
NDT funds	965		950
Auction rate securities	8	[2]	8	[2]
Total assets	2,693		2,821
Price risk management liabilities:
Energy commodities liabilities	1,163		1,217
Total price risk management liabilities	1,163		1,217
Cash and cash equivalents
Price risk management assets:
NDT funds	20		19
U.S. large-cap
Price risk management assets:
NDT funds	620		611
U.S. mid/small-cap
Price risk management assets:
NDT funds	93		89
U.S. Treasury
Price risk management assets:
NDT funds	97		99
U.S. government sponsored agency
Price risk management assets:
NDT funds	8		9
Municipality
Price risk management assets:
NDT funds	76		76
Investment-grade corporate
Price risk management assets:
NDT funds	45		42
Other
Price risk management assets:
NDT funds	3		3
Receivables/payables, net
Price risk management assets:
NDT funds	3		2
Level 1
Assets
Cash and cash equivalents	221		352
Restricted cash and cash equivalents	201	[1]	193	[1]
Price risk management assets:
Energy commodities assets	2		6
Total price risk management assets	2		6
NDT funds	617		609
Total assets	1,041		1,160
Price risk management liabilities:
Energy commodities liabilities	2		5
Total price risk management liabilities	2		5
Level 1 | Cash and cash equivalents
Price risk management assets:
NDT funds	20		19
Level 1 | U.S. large-cap
Price risk management assets:
NDT funds	461		454
Level 1 | U.S. mid/small-cap
Price risk management assets:
NDT funds	38		37
Level 1 | U.S. Treasury
Price risk management assets:
NDT funds	97		99
Level 1 | Receivables/payables, net
Price risk management assets:
NDT funds	1		0
Level 2
Price risk management assets:
Energy commodities assets	1,136		1,171
Total price risk management assets	1,136		1,171
NDT funds	348		341
Total assets	1,484		1,512
Price risk management liabilities:
Energy commodities liabilities	1,130		1,182
Total price risk management liabilities	1,130		1,182
Level 2 | U.S. large-cap
Price risk management assets:
NDT funds	159		157
Level 2 | U.S. mid/small-cap
Price risk management assets:
NDT funds	55		52
Level 2 | U.S. government sponsored agency
Price risk management assets:
NDT funds	8		9
Level 2 | Municipality
Price risk management assets:
NDT funds	76		76
Level 2 | Investment-grade corporate
Price risk management assets:
NDT funds	45		42
Level 2 | Other
Price risk management assets:
NDT funds	3		3
Level 2 | Receivables/payables, net
Price risk management assets:
NDT funds	2		2
Level 3
Price risk management assets:
Energy commodities assets	160		141
Total price risk management assets	160		141
Auction rate securities	8	[2]	8	[2]
Total assets	168		149
Price risk management liabilities:
Energy commodities liabilities	31		30
Total price risk management liabilities	$31		$30
[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.

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) (Recurring, Level 3, USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Fair Value, Net Assets (Liabilities) Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	$119	$40
Total realized/unrealized gains (losses) included in earnings	-17	-135
Sales		-3
Settlements	30	128
Transfers into Level 3	4
Transfers out of Level 3	1
Balance at end of period	137	30
Energy Commodities, Net
Fair Value, Net Assets (Liabilities) Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	111	24
Total realized/unrealized gains (losses) included in earnings	-17	-135
Settlements	30	128
Transfers into Level 3	4
Transfers out of Level 3	1
Balance at end of period	129	17
Auction Rate Securities
Fair Value, Net Assets (Liabilities) Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period		16	8
Sales		-3
Balance at end of period	$8	$13	$8

Fair_Value_Measurements_and_Cr5

Fair Value Measurements and Credit Concentration (Net Assets and Liabilities Measured on Recurring Basis Level 3 Significant Unobservable Inputs) (Details) (Recurring, Level 3, USD $)	3 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
Energy Commodities, Net | Natural gas contracts
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair value of net asset and (liability)	49	[1]	59	[1]
Energy Commodities, Net | Natural gas contracts | Discounted Cash Flow | Minimum
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	11.00%	[2]	11.00%	[2]
Energy Commodities, Net | Natural gas contracts | Discounted Cash Flow | Maximum
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	100.00%	[2]	100.00%	[2]
Energy Commodities, Net | Natural gas contracts | Discounted Cash Flow | Weighted Average
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	43.00%	[2]	52.00%	[2]
Energy Commodities, Net | Power sales contracts
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair value of net asset and (liability)	1	[3]	-1	[3]
Energy Commodities, Net | Power sales contracts | Discounted Cash Flow | Minimum
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	10.00%	[2]	10.00%	[2]
Energy Commodities, Net | Power sales contracts | Discounted Cash Flow | Maximum
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	100.00%	[2]	100.00%	[2]
Energy Commodities, Net | Power sales contracts | Discounted Cash Flow | Weighted Average
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	82.00%	[2]	59.00%	[2]
Energy Commodities, Net | FTR purchase contracts
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair value of net asset and (liability)			3	[4]
Energy Commodities, Net | FTR purchase contracts | Discounted Cash Flow | Minimum
Fair Value Inputs [Abstract]
Historical settled prices used to model forward prices			100.00%	[2]
Energy Commodities, Net | FTR purchase contracts | Discounted Cash Flow | Maximum
Fair Value Inputs [Abstract]
Historical settled prices used to model forward prices			100.00%	[2]
Energy Commodities, Net | FTR purchase contracts | Discounted Cash Flow | Weighted Average
Fair Value Inputs [Abstract]
Historical settled prices used to model forward prices			100.00%	[2]
Energy Commodities, Net | Heat rate options
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair value of net asset and (liability)	79	[5]	50	[5]
Energy Commodities, Net | Heat rate options | Discounted Cash Flow | Minimum
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	22.00%	[2]	23.00%	[2]
Energy Commodities, Net | Heat rate options | Discounted Cash Flow | Maximum
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	44.00%	[2]	51.00%	[2]
Energy Commodities, Net | Heat rate options | Discounted Cash Flow | Weighted Average
Fair Value Inputs [Abstract]
Proprietary model used to calculate forward prices	40.00%	[2]	45.00%	[2]
Auction Rate Securities
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair value of net asset and (liability)	8	[6]	8	[6]
Auction Rate Securities | Discounted Cash Flow | Minimum
Fair Value Inputs [Abstract]
Modeled from SIFMA Index	50.00%	[2]	51.00%	[2]
Auction Rate Securities | Discounted Cash Flow | Maximum
Fair Value Inputs [Abstract]
Modeled from SIFMA Index	69.00%	[2]	69.00%	[2]
Auction Rate Securities | Discounted Cash Flow | Weighted Average
Fair Value Inputs [Abstract]
Modeled from SIFMA Index	56.00%	[2]	63.00%	[2]
[1]	As the forward price of natural gas increases/(decreases), the fair value of purchase contracts increases/(decreases). As the forward price of natural gas increases/(decreases), the fair value of sales 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.
[3]	As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases. As volumetric assumptions for contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases). As volumetric assumptions for contracts in a loss position increase/(decrease), the fair value of the contracts (decreases)/increases.
[4]	As the forward implied spread increases/(decreases), the fair value of the contracts increases/(decreases).
[5]	The proprietary model used to calculate fair value incorporates market heat rates, correlations and volatilities. As the market implied heat rate increases/(decreases), the fair value of the contracts increases/(decreases).
[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).

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) (Recurring, Level 3, USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Net gains and losses on assets and liabilities [Abstract]
Total gains (losses) included in earnings	($17)	($135)
Energy Commodities, Net | Unregulated wholesale energy
Net gains and losses on assets and liabilities [Abstract]
Total gains (losses) included in earnings	21	-89
Change in unrealized gains (losses) relating to positions still held at the reporting date	25	-13
Energy Commodities, Net | Unregulated Retail Energy
Net gains and losses on assets and liabilities [Abstract]
Total gains (losses) included in earnings	-40	-63
Change in unrealized gains (losses) relating to positions still held at the reporting date	-9	-33
Energy Commodities, Net | Energy purchases
Net gains and losses on assets and liabilities [Abstract]
Total gains (losses) included in earnings	2	17
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) (Details) (Nonrecurring, USD $)	1 Months Ended		3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2014
Kerr Dam Project
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Loss	$18		$18	[1]
Carrying Amount | Kerr Dam Project
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Nonrecurring measurement asset value	47	[2]	47	[2]
Level 3 | Kerr Dam Project
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Nonrecurring measurement asset value	29		29
Fair value of net asset and (liability)	$29	[3]	$29	[3]
Discounted Cash Flow | Minimum | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Proprietary model used to calculate plant value			38.00%	[3]
Discounted Cash Flow | Maximum | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Proprietary model used to calculate plant value			38.00%	[3]
Discounted Cash Flow | Weighted Average | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Proprietary model used to calculate plant value			38.00%	[3]
[1]	The loss on the Kerr Dam Project is included in "Income (Loss) from Discontinued Operations (net of income taxes)" on the 2014 Statement of Income.
[2]	Represents carrying value before fair value measurement.
[3]	The range and weighted average represent the percentage of fair value derived from the unobservable inputs.

Fair_Value_Measurements_and_Cr8

Fair Value Measurements and Credit Concentration (Financial Instruments Not Recorded at Fair Value and Credit Concentration) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Credit Concentration Associated with Financial Instruments (Numeric) [Abstract]
Gross credit exposure from energy trading partners	$692
Net credit exposure to energy trading partners	402
Dollar exposure to top ten energy trading counterparties	220
Percentage exposure to top ten energy trading counterparties	55.00%
Number of counterparties in top ten that have investment grade credit rating	8
Percentage of top ten's exposure that consists of counterparties with investment grade credit rating	75.00%
Carrying Amount
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	2,217	2,218
Fair Value
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$2,221	$2,204

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities (Intro) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
	MW
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Obligation to return cash collateral obligation under master netting arrangement	$11		$11
Commodity Price Risk (Non-trading) [Line Items]
Baseload generation fleet capacity (in MW)	6,496
Intermediate and peaking generation fleet capacity (in MW)	3,252
Commodity Price Risk (Non-trading) [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	18
No or insignificant amounts previously recorded in AOCI reclassified to earnings related to commodity price risk cash flow hedge contracts	There were no such reclassifications for the three months ended MarchB 31, 2015 and 2014.	There were no such reclassifications for the three months ended MarchB 31, 2015 and 2014.
No or immaterial hedge ineffectiveness related to commodity price risk cash flow hedge contracts	There were no such reclassifications for the three months ended MarchB 31, 2015 and 2014.	There were no such reclassifications for the three months ended MarchB 31, 2015 and 2014.
Commodity Price Risk Nontrading Economic Activity Numeric [Abstract]
Year of expiration of the maximum maturity date of economic activity derivative contracts	2020
Unregulated wholesale energy
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]
Pre-tax gain (loss)	-92	-789
Unregulated Retail Energy
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]
Pre-tax gain (loss)	-13	-26
Fuel
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]
Pre-tax gain (loss)	0	-1
Energy purchases
Pre-tax Gains (Losses) of Economic Activity - Unregulated Business (Details) [Abstract]
Pre-tax gain (loss)	$145	580

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities (Commodity Volumes) (Details)	Mar. 31, 2015
	MWh
Sales contracts | Power | 2015
Derivative [Line Items]
Notional amount (in units)	30,874,062	[1],[2]
Sales contracts | Power | 2016
Derivative [Line Items]
Notional amount (in units)	8,521,382	[1]
Sales contracts | Power | 2017
Derivative [Line Items]
Notional amount (in units)	248,329	[1]
Sales contracts | Capacity | 2015
Derivative [Line Items]
Notional amount (in units)	3,998	[1],[2]
Sales contracts | Capacity | 2016
Derivative [Line Items]
Notional amount (in units)	878	[1]
Purchase contracts | Power | Thereafter
Derivative [Line Items]
Notional amount (in units)	2,236,333	[1]
Purchase contracts | Capacity | 2017
Derivative [Line Items]
Notional amount (in units)	6	[1]
Purchase contracts | Capacity | Thereafter
Derivative [Line Items]
Notional amount (in units)	3	[1]
Purchase contracts | Gas | 2015
Derivative [Line Items]
Notional amount (in units)	157,995,389	[1],[2]
Purchase contracts | Gas | 2016
Derivative [Line Items]
Notional amount (in units)	87,545,701	[1]
Purchase contracts | Gas | 2017
Derivative [Line Items]
Notional amount (in units)	13,742,416	[1]
Purchase contracts | Gas | Thereafter
Derivative [Line Items]
Notional amount (in units)	20,314,625	[1]
Purchase contracts | FTRs | 2015
Derivative [Line Items]
Notional amount (in units)	532	[1],[2]
Purchase contracts | FTRs | 2016
Derivative [Line Items]
Notional amount (in units)	0	[1]
Purchase contracts | FTRs | 2017
Derivative [Line Items]
Notional amount (in units)	0	[1]
Purchase contracts | FTRs | Thereafter
Derivative [Line Items]
Notional amount (in units)	0	[1]
Purchase contracts | Oil | 2015
Derivative [Line Items]
Notional amount (in units)	300,328	[1],[2]
Purchase contracts | Oil | 2016
Derivative [Line Items]
Notional amount (in units)	387,429	[1]
Purchase contracts | Oil | 2017
Derivative [Line Items]
Notional amount (in units)	257,483	[1]
Purchase contracts | Oil | Thereafter
Derivative [Line Items]
Notional amount (in units)	60,000	[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.
[2]	Represents balance of the current year.

Derivative_Instruments_and_Hed5

Derivative Instruments and Hedging Activities (Fair Values) (Details) (Not Designated as Hedging Instrument, USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Fair Values by Balance Sheet Location [Abstract]
Asset value	$1,298	[1]	$1,318	[1]
Liability value	1,163	[1]	1,217	[1]
Current Assets | Commodity Contract
Fair Values by Balance Sheet Location [Abstract]
Asset value	988	[1]	1,079	[1]
Noncurrent Assets | Commodity Contract
Fair Values by Balance Sheet Location [Abstract]
Asset value	310	[1]	239	[1]
Current Liabilities | Commodity Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	904	[1]	1,024	[1]
Noncurrent Liabilities | Commodity Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	$259	[1]	$193	[1]
[1]	Represents the location on the Balance Sheets.

Derivative_Instruments_and_Hed6

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in OCI on derivative (effective portion)	$0	$0
Cash Flow Hedges | Commodity Contract
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	7	9
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0
Cash Flow Hedges | Commodity Contract | Unregulated wholesale energy
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0
Cash Flow Hedges | Commodity Contract | Energy purchases
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0
Cash Flow Hedges | Commodity Contract | Depreciation
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0
Cash Flow Hedges | Commodity Contract | Discontinued operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)		0
Not Designated as Hedging Instrument | Commodity Contract
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	-75	-745
Not Designated as Hedging Instrument | Commodity Contract | Unregulated wholesale energy
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	-229	-3,042	[1]
Not Designated as Hedging Instrument | Commodity Contract | Unregulated Retail Energy
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	-39	-64
Not Designated as Hedging Instrument | Commodity Contract | Fuel
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	-3	-1
Not Designated as Hedging Instrument | Commodity Contract | Energy purchases
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net	196	2,364	[2]
Not Designated as Hedging Instrument | Commodity Contract | Discontinued operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivative, net		-2
Reclassification out of AOCI | Qualifying derivatives | Cash Flow Hedges | Commodity Contract | Unregulated wholesale energy
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	-2	-1
Reclassification out of AOCI | Qualifying derivatives | Cash Flow Hedges | Commodity Contract | Energy purchases
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	8	7
Reclassification out of AOCI | Qualifying derivatives | Cash Flow Hedges | Commodity Contract | Depreciation
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	1	1
Reclassification out of AOCI | Qualifying derivatives | Cash Flow Hedges | Commodity Contract | Discontinued operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)		$2
[1]	2014 includes significant realized and unrealized losses on physical and financial commodity sales contracts due to the unusually cold weather.
[2]	2014 includes significant realized and unrealized gains on physical and financial commodity purchase contracts due to the unusually cold weather.

Derivative_Instruments_and_Hed7

Derivative Instruments and Hedging Activities (Offseting Derivative Instruments and Credit Risk-Related Features) (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Derivative, Credit Risk Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$122
Aggregate fair value of collateral posted on these derivative instruments	118
Aggregate fair value of additional collateral requirements, primarily related to further adequate assurance features	32	[1]
Energy commodities
Offsetting Assets And Liabilities [Line Items]
Asset value	1,298		1,318
Derivative instruments, eligible for offset - assets	990		1,060
Cash collateral received eligible for offset - assets	11		10
Derivative Asset	297		248
Liability value	1,163		1,217
Derivative instruments, eligible for offset - liabilities	990		1,060
Cash collateral pledged, eligible for offset - liabilities	49		58
Derivative Liability	$124		$99
[1]	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at Beginning of Period	$425
Accretion expense	8
Balance at End of Period	$433

AvailableforSale_Securities_De

Available-for-Sale Securities (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014
Available-for-sale Securities, Debt Maturities, Amortized Cost Basis, Fiscal Year Maturity [Abstract]
Amortized cost - maturity less than 1 year	$11
Amortized cost - maturity between 1 and 5 years	82
Amortized cost - maturity between 6 and 10 years	67
Amortized cost - maturity in excess of 10 years	66
Amortized cost total	226
Fair value - maturity less than 1 year	11
Fair value - maturity between 1 and 5 years	84
Fair value - maturity between 6 and 10 years	70
Fair value - maturity in excess of 10 years	72
Fair value total	237
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Proceeds from sales of NDT securities	38		27
Other proceeds from sales	0		3
Gross realized gains	5	[1]	3	[1]
Gross realized losses	3	[1]	1	[1]
NDT Funds
Available-for-sale Securities, Balance Sheet, Reported Amounts [Abstract]
Amortized cost	528				522
Gross unrealized gains	438				428
Gross unrealized losses	1				0
Fair value	965				950
NDT Funds | Cash and cash equivalents
Available-for-sale Securities, Balance Sheet, Reported Amounts [Abstract]
Amortized cost	20				19
Gross unrealized gains	0				0
Gross unrealized losses	0				0
Fair value	20				19
NDT Funds | Equity securities
Available-for-sale Securities, Balance Sheet, Reported Amounts [Abstract]
Amortized cost	287				283
Gross unrealized gains	426				417
Gross unrealized losses	0				0
Fair value	713				700
NDT Funds | Debt securities
Available-for-sale Securities, Balance Sheet, Reported Amounts [Abstract]
Amortized cost	218				218
Gross unrealized gains	12				11
Gross unrealized losses	1				0
Fair value	229				229
NDT Funds | Receivables/payables, net
Available-for-sale Securities, Balance Sheet, Reported Amounts [Abstract]
Amortized cost	3				2
Gross unrealized gains	0				0
Gross unrealized losses	0				0
Fair value	3				2
Auction Rate Securities
Available-for-sale Securities, Balance Sheet, Reported Amounts [Abstract]
Amortized cost	8				8
Gross unrealized gains	0				0
Gross unrealized losses	0				0
Fair value	$8				$8
[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 $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at beginning of period	($23)	$77
Amounts arising during the period	5	5
Reclassifications from accumulated other comprehensive income	-1	-4
Total other comprehensive income (loss)	4	1
Balance at end of period	-19	78
Available- for-sale securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at beginning of period	202	173
Amounts arising during the period	5	5
Reclassifications from accumulated other comprehensive income	-1	-1
Total other comprehensive income (loss)	4	4
Balance at end of period	206	177
Qualifying derivatives
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at beginning of period	63	88
Amounts arising during the period	0	0
Reclassifications from accumulated other comprehensive income	-4	-5
Total other comprehensive income (loss)	-4	-5
Balance at end of period	59	83
Prior service costs
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at beginning of period	7	-4
Amounts arising during the period	0	0
Reclassifications from accumulated other comprehensive income	0	1
Total other comprehensive income (loss)	0	1
Balance at end of period	7	-3
Actuarial gain (loss)
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at beginning of period	-295	-180
Amounts arising during the period	0	0
Reclassifications from accumulated other comprehensive income	4	1
Total other comprehensive income (loss)	4	1
Balance at end of period	($291)	($179)

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Affected Line Item on the Statements of Income [Line Items]
Unregulated wholesale energy	$522	($1,457)
Energy purchases	-1	1,804
Other Income (Expense) - net	7	6
Total Pre-tax	149	-105
Income Taxes	-53	47
Income (Loss) from Continuing Operations After Income Taxes	96	-58
Reclassification out of AOCI
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations After Income Taxes	1	4
Reclassification out of AOCI | Available-for-sale securities
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	2	2
Total Pre-tax	2	2
Income Taxes	-1	-1
Income (Loss) from Continuing Operations After Income Taxes	1	1
Reclassification out of AOCI | Qualifying derivatives
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	7	9
Income Taxes	-3	-4
Income (Loss) from Continuing Operations After Income Taxes	4	5
Reclassification out of AOCI | Qualifying derivatives | Energy commodities
Affected Line Item on the Statements of Income [Line Items]
Unregulated wholesale energy	-2	-1
Energy purchases	8	7
Discontinued operations	0	2
Other Income (Expense) - net	1	1
Reclassification out of AOCI | Defined benefit plans
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	-7	-4
Income Taxes	3	2
Income (Loss) from Continuing Operations After Income Taxes	-4	-2
Reclassification out of AOCI | Defined benefit plans | Prior service costs
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	0	-2
Reclassification out of AOCI | Defined benefit plans | Net actuarial loss
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	($7)	($2)