NRG Energy (NRG) 10-Q 7 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Jul. 31, 2014
Document And Entity Information [Abstract]	'	'
Entity Registrant Name	'NRG ENERGY, INC.	'
Entity Central Index Key	'0001013871	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	337,710,439
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended		6 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Operating Revenues	'	'	'	'
Total operating revenues	$3,621	$2,929	$7,107	$5,010
Operating Costs and Expenses	'	'	'	'
Cost of operations	2,817	2,051	5,550	3,804
Depreciation and amortization	386	313	721	620
Selling, general and administrative	268	230	494	457
Acquisition-related transaction and integration costs	40	27	52	69
Development activity expenses	21	21	40	39
Total operating costs and expenses	3,532	2,642	6,857	4,989
Gain on sale of assets	0	0	19	0
Operating Income	89	287	269	21
Other Income/(Expense)	'	'	'	'
Equity in earnings of unconsolidated affiliates	14	8	21	11
Other income, net	5	0	16	4
Loss on debt extinguishment	-40	-21	-81	-49
Interest expense	-274	-206	-529	-402
Total other expense	-295	-219	-573	-436
(Loss)/Income Before Income Taxes	-206	68	-304	-415
Income tax benefit	-126	-63	-157	-215
Net (Loss)/Income	-80	131	-147	-200
Less: Net income attributable to noncontrolling interest	17	7	6	8
Net (Loss)/Income Attributable to NRG Energy, Inc.	-97	124	-153	-208
Dividends for preferred shares	3	3	5	5
(Loss)/Income Available for Common Stockholders	($100)	$121	($158)	($213)
(Loss)/Earnings Per Share Attributable to NRG Energy, Inc. Common Stockholders	'	'	'	'
Weighted average number of common shares outstanding	337	323	331	323
(Loss)/Earnings per Weighted Average Common Share — Basic	($0.30)	$0.37	($0.48)	($0.66)
Weighted average number of common shares outstanding — diluted	337	327	331	323
Loss per Weighted Average Common Share — Diluted	($0.30)	$0.37	($0.48)	($0.66)
Dividends Per Common Share	$0.14	$0.12	$0.26	$0.21

Condensed_Consolidated_Stateme1

Condensed Consolidated Statement of Comprehensive Loss Income (Parenthetical) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Unrealized gain/loss on derivatives, income tax benefit	($19)	$17	($147)	($200)
Foreign currency translation adjustments, income tax benefit	-4	-19	-28	24
Available-for-sale securities, income tax expense	-2	0	2	-19
Defined benefit plans, income tax expense	($20)	($20)	($4)	($2)

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Comprehensive Income/(Loss) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net (Loss)/Income	($80)	$131	($147)	($200)
Other Comprehensive (Loss)/Income, net of tax	'	'	'	'
Unrealized (loss)/gain on derivatives, net of income tax (benefit)/expense of $(2), $12, $(5), and $3	-19	17	-28	24
Foreign currency translation adjustments, net of income tax expense/(benefit) of $3, $(12), $5, and $(12)	-3	-19	3	-19
Available-for-sale securities, net of income tax expense of $3, $2, $5, and $1	7	0	13	2
Defined benefit plans, net of tax (benefit)/expense of $(17), $9, $(17), and $4	10	20	12	25
Other comprehensive (loss)/income	-5	18	0	32
Comprehensive (Loss)/Income	-85	149	-147	-168
Less: Comprehensive income/(loss) attributable to noncontrolling interest	-12	-7	3	-8
Comprehensive (Loss)/Income Attributable to NRG Energy, Inc.	-97	142	-144	-176
Dividends for preferred shares	3	3	5	5
Comprehensive (Loss)/Income Available for Common Stockholders	($100)	$139	($149)	($181)

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets	'	'
Cash and cash equivalents	$1,481	$2,254
Funds deposited by counterparties	9	63
Restricted cash	286	268
Accounts receivable — trade, less allowance for doubtful accounts of $26 and $40	1,482	1,214
Inventory	996	898
Derivative instruments	1,701	1,328
Cash collateral paid in support of energy risk management activities	572	276
Deferred income taxes	79	258
Renewable energy grant receivable, net	614	539
Prepayments and other current assets	537	498
Total current assets	7,757	7,596
Property, plant and equipment, net of accumulated depreciation of $7,230 and $6,573	21,576	19,851
Other Assets	'	'
Equity investments in affiliates	865	453
Notes receivable, less current portion	85	73
Goodwill	2,116	1,985
Intangible assets, net of accumulated amortization of $1,268 and $1,977	1,434	1,140
Nuclear decommissioning trust fund	576	551
Derivative instruments	413	311
Deferred income taxes	1,500	1,202
Other non-current assets	1,307	740
Total other assets	8,296	6,455
Total Assets	37,629	33,902
Current Liabilities	'	'
Current portion of long-term debt and capital leases	833	1,050
Accounts payable	1,103	1,038
Derivative instruments	1,736	1,055
Cash collateral received in support of energy risk management activities	9	63
Accrued expenses and other current liabilities	1,065	998
Total current liabilities	4,746	4,204
Other Liabilities	'	'
Long-term debt and capital leases	18,165	15,767
Nuclear decommissioning reserve	302	294
Nuclear decommissioning trust liability	336	324
Deferred income taxes	71	22
Derivative instruments	354	195
Out-of-market contracts	1,175	1,177
Other non-current liabilities	1,254	1,201
Total non-current liabilities	21,657	18,980
Total Liabilities	26,403	23,184
3.625% convertible perpetual preferred stock (at liquidation value, net of issuance costs)	249	249
Commitments and Contingencies	'	'
Stockholders’ Equity	'	'
Common stock	4	4
Additional paid-in capital	8,303	7,840
Retained earnings	3,445	3,695
Less treasury stock, at cost — 77,275,933 and 77,347,528 shares, respectively	-1,940	-1,942
Accumulated other comprehensive income	5	5
Noncontrolling interest	1,160	867
Total Stockholders’ Equity	10,977	10,469
Total Liabilities and Stockholders’ Equity	$37,629	$33,902

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Accounts receivable - trade, allowance for doubtful accounts	$26	$40
Property, plant and equipment, accumulated depreciation	7,230	6,573
Intangible assets, accumulated amortization	$1,268	$1,977
3.625% convertible perpetual preferred stock, interest rate (as a percentage)	3.63%	3.63%
Treasury stock, shares (in shares)	77,275,933	77,347,528

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements Of Cash Flows (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash Flows from Operating Activities	'	'
Net (Loss)/Income	($147)	($200)
Adjustments to reconcile net loss to net cash provided/(used) by operating activities:	'	'
Distributions and equity in earnings of unconsolidated affiliates	39	5
Depreciation and amortization	721	620
Provision for bad debts	30	23
Amortization of nuclear fuel	20	16
Amortization of financing costs and debt discount/premiums	-9	-26
Adjustment for debt extinguishment	21	-16
Amortization of intangibles and out-of-market contracts	22	124
Amortization of unearned equity compensation	24	24
Changes in deferred income taxes and liability for uncertain tax benefits	-514	-224
Changes in nuclear decommissioning trust liability	6	25
Changes in derivative instruments	535	174
Changes in collateral deposits supporting energy risk management activities	-297	-158
Gain on sale of emission allowances	-2	0
Gain on sale of assets	-19	0
Cash used by changes in other working capital	-64	-465
Net Cash Provided/(Used) by Operating Activities	370	-78
Cash Flows from Investing Activities	'	'
Acquisitions of businesses, net of cash acquired	-1,817	-39
Capital expenditures	-507	-1,281
Increase in restricted cash, net	-6	-31
Decrease/(Increase) in restricted cash to support equity requirements for U.S. DOE funded projects	21	-16
Decrease/(Increase) in notes receivable	2	-11
Investments in nuclear decommissioning trust fund securities	-340	-233
Proceeds from sales of nuclear decommissioning trust fund securities	334	208
Proceeds from renewable energy grants	429	48
Proceeds from sale of assets, net of cash disposed of	77	0
Cash proceeds to fund cash grant bridge loan payment	57	0
Other	-3	-20
Net Cash Used by Investing Activities	-1,753	-1,375
Cash Flows from Financing Activities	'	'
Payment of dividends to common and preferred stockholders	-91	-73
Payment for treasury stock	0	-25
Net (payments for)/receipts from settlement of acquired derivatives that include financing elements	-167	171
Proceeds from issuance of long-term debt	3,886	1,472
Contributions and sale proceeds from noncontrolling interest in subsidiaries	10	33
Proceeds from issuance of common stock	8	9
Payment of debt issuance costs	-43	-35
Payments for short and long-term debt	-2,969	-816
Net Cash Provided by Financing Activities	634	736
Effect of exchange rate changes on cash and cash equivalents	-24	-2
Net Decrease in Cash and Cash Equivalents	-773	-719
Cash and Cash Equivalents at Beginning of Period	2,254	2,087
Cash and Cash Equivalents at End of Period	$1,481	$1,368

Basis_of_Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies [Text Block]	'
	Basis of Presentation
	NRG Energy, Inc., or NRG or the Company, is a competitive power and energy company that produces, sells and delivers energy and energy services in major competitive power markets in the United States while positioning itself as a leader in the way residential, industrial and commercial consumers think about and use energy products and services. NRG owns and operates power generation facilities; engages in the trading of energy, capacity and related products; transacts in and trades fuel and transportation services and directly sells energy, services, and innovative, sustainable products to retail customers. The Company sells retail electricity products and services under the name “NRG” and various brands owned by NRG. Finally, NRG is a leader in the deployment and commercialization of potentially transformative technologies, like electric vehicles, Distributed Solar and smart meter/home automation technology that collectively have the potential to fundamentally change the nature of the power industry and the role of the national electric transmission grid and distribution system.
	The accompanying unaudited interim condensed consolidated financial statements have been prepared in accordance with the SEC's regulations for interim financial information and with the instructions to Form 10-Q. Accordingly, they do not include all of the information and notes required by generally accepted accounting principles for complete financial statements. The following notes should be read in conjunction with the accounting policies and other disclosures as set forth in the notes to the consolidated financial statements in the Company's 2013 Form 10-K. Interim results are not necessarily indicative of results for a full year.
	In the opinion of management, the accompanying unaudited interim condensed consolidated financial statements contain all material adjustments consisting of normal and recurring accruals necessary to present fairly the Company's consolidated financial position as of June 30, 2014, and the results of operations, comprehensive loss and cash flows for the three and six months ended June 30, 2014, and 2013.
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. Certain prior period depreciation amounts have been recast to revise provisional purchase accounting estimates for the GenOn acquisition.
	Reclassifications
	Certain prior year amounts have been reclassified for comparative purposes. The reclassifications did not affect results from operations or cash flows.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Other Cash Flow Information
	NRG’s investing activities exclude capital expenditures of $127 million which were accrued and unpaid at June 30, 2014.
	Noncontrolling Interest
	The following table reflects the changes in NRG's noncontrolling interest balance:
		(In millions)
	Balance as of December 31, 2013	$	867
	Acquisition of EME	380
	Sale of assets to NRG Yield, Inc.	(41		)
	Non-cash adjustments for equity component of NRG Yield, Inc. convertible notes	23
	Non-cash adjustments to noncontrolling interest	(76		)
	Contributions from noncontrolling interest	25
	Distributions to noncontrolling interest	(15		)
	Comprehensive loss attributable to noncontrolling interest	(3		)
	Balance as of June 30, 2014	$	1,160
	Recent Accounting Developments
	ASU 2014-09 - In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or ASU No. 2014-09. The amendments of ASU No. 2014-09 complete the joint effort between the FASB and the International Accounting Standards Board, or IASB, to develop a common revenue standard for U.S. GAAP and International Financial Reporting Standards, or IFRS, and to improve financial reporting. The guidance in ASU No. 2014-09 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for the goods or services provided and establishes the following steps to be applied by an entity: (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies the performance obligation. The guidance of ASU No. 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods therein. Early adoption is not permitted. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position.
	ASU 2013-11 - In July 2013, the FASB issued ASU No. 2013-11, Income Taxes (Topic 740) Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists, or ASU No. 2013-11.  The amendments of ASU No. 2013-11, which were adopted on January 1, 2014, require an entity to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, as a reduction of a deferred tax asset for a net operating loss, or NOL, a similar tax loss or tax credit carryforward rather than a liability when the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and the entity intends to use the deferred tax asset for that purpose.  The adoption of this standard did not impact the Company's results of operations or cash flows as the unrecognized tax benefits relate to state issues and the Company either has no NOL's or the NOL's are limited for that particular jurisdiction.

Business_Acquisitions_and_Disp

Business Acquisitions and Dispositions	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Business Acquisitions and Dispositions	'
	Business Acquisitions and Dispositions
	Disposition of 50% Interest in Petra Nova Parish Holdings LLC
	On July 3, 2014, the Company, through its wholly owned subsidiary Petra Nova Holdings LLC, sold 50% of its interest in Petra Nova Parish Holdings LLC to JX Nippon Oil Exploration (EOR) Limited, a wholly owned subsidiary of JX Nippon Oil & Gas Exploration Corporation.  As a result of the sale, the Company no longer has a controlling interest in and has deconsolidated Petra Nova Parish Holdings LLC as of the date of the sale. On July 7, 2014, the Company made its initial capital contribution into the partnership of $35 million, which was funded with the sale proceeds of $76 million. On March 3, 2014, Petra Nova CCS I LLC, a wholly owned subsidiary of Petra Nova Parish Holdings LLC, entered into a fixed-price agreement to build and operate a CCS-EOR at the W.A. Parish facility with a consortium of Mitsubishi Heavy Industries America, Inc. and TIC - The Industrial Company.  Notice to proceed for the construction on the CCS-EOR was issued on July 15, 2014, and commercial operation is expected in late 2016.
	The joint venture also owns a 75 MW peaking unit at W.A. Parish, which achieved commercial operations on June 26, 2013. The peaking unit will be converted into a cogeneration facility to provide power and steam to the CCS-EOR.  The CCS-EOR is being financed by: (i) up to $167 million from a U.S. DOE CCPI grant of which $7 million has already been received from the grant in the initial design and engineering phase, (ii) $250 million in loans provided by the Japan Bank for International Cooperation and Mizuho Bank, Ltd., and (iii) approximately $300 million in equity contributions from each of the Company and JX Nippon. The Company’s contribution will include investments already made during the development of the project.
	On July 14, 2014, Petra Nova Parish Holdings LLC entered into two credit facilities, or the Petra Nova Parish Credit Agreements, to fund the cost of construction of the CCS-EOR at the W.A. Parish facility. The Petra Nova Parish Credit Agreements are comprised of a $75 million Nippon Export and Investment Insurance, or NEXI, covered loan and a $175 million Japan Bank for International Cooperation, or JBIC, facility. The NEXI covered loan has an interest rate of LIBOR plus an applicable margin of 1.75% and the JBIC facility has an interest rate of LIBOR plus an applicable margin of 0.50% during the construction phase which escalates to an applicable margin of 1.50% upon completion of the CCS-EOR. Both credit facilities mature in April 2026. NRG has guaranteed its 50% share of the obligations under the Petra Nova Parish Credit Agreements.
	Sales of Assets to NRG Yield, Inc.
	On June 30, 2014, the Company sold the following facilities to NRG Yield, Inc.: High Desert, Kansas South, and El Segundo Energy Center. NRG Yield, Inc. paid total cash consideration of $357 million, which represents a base purchase price of $349 million and $8 million of working capital adjustments, plus assumed project level debt of approximately $612 million. The sale was recorded as a transfer of entities under common control and the related assets were transferred at carrying value.
	Pending Acquisition
	On June 3, 2014, NRG Yield Operating LLC, or Yield Operating, a consolidated subsidiary of the Company, entered into a purchase and sale agreement with Terra-Gen Finance Company, LLC and certain of its affiliates to acquire 100% of the membership interests of Alta Wind Asset Management Holdings, LLC, Alta Wind Company, LLC, Alta Wind X Holding Company, LLC, and Alta Wind XI Holding Company, LLC, which collectively owns seven wind facilities that total 947 MWs located in Tehachapi, California and a portfolio of land leases, or the Alta Wind Assets. The purchase price of the Alta Wind Assets is $870 million, as well as working capital adjustments, plus the assumption of $1.6 billion in non-recourse project level debt. The acquisition, which is subject to customary closing conditions, including certain regulatory approvals, is expected to close during the third quarter of 2014. Power generated by the Alta Wind facility is sold to Southern California Edison under long-term power purchase agreements with 21 years of remaining contract life for Phases I-V and 22 years, beginning in 2016, for Phases X and XI.
	In order to fund the purchase price of the acquisition, NRG Yield, Inc. issued 12,075,000 shares of its Class A common stock on July 29,2014 for net proceeds of $630 million. In addition, on August 5, 2014, Yield Operating issued $500 million in aggregate principal amount at par of 5.375% senior notes due August 2024. Interest on the notes is payable semi-annually on February 15 and August 15 of each year, commencing on February 15, 2015. The notes are senior unsecured obligations of Yield Operating and are guaranteed by NRG Yield LLC, Yield Operating’s parent company, and by certain of Yield Operating’s wholly owned current and future subsidiaries.
	Acquisition of Dominion's Competitive Electric Retail Business
	On March 31, 2014, the Company acquired the competitive retail electricity business of Dominion Resources, Inc., or Dominion. The acquisition of Dominion's competitive retail electricity business increased NRG’s retail portfolio by approximately 217,000 customers as of June 30, 2014, and is expected to increase NRG’s retail portfolio by approximately 500,000 customers in the aggregate by the end of 2014. The acquisition supports NRG's ongoing efforts to expand the Company's retail footprint in the Northeast and to grow its retail position in Texas. The Company paid approximately $195 million as cash consideration for the acquisition, including $165 million of purchase price and $30 million paid for working capital balances, which was funded by cash on hand. The purchase price was provisionally allocated to the following: $50 million to accounts receivable-trade, $62 million to customer relationships, $9 million to trade names, $10 million to current assets, $20 million to derivative assets, $46 million to current and non-current liabilities, and goodwill of $90 million which is not deductible for U.S. income tax purposes in future periods. The factors that resulted in goodwill arising from the acquisition include the revenues associated with new customers in new regions and through the synergies associated with combining a new retail business with the Company's generation assets. The acquired assets and liabilities are included within the Retail segment. The provisional amounts are subject to revision until the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date. Any changes to the fair value assessments will affect the value of goodwill. The allocation of the purchase price may be modified up to one year from the date of the acquisition as more information is obtained about the fair value of assets acquired and liabilities assumed.
	EME Acquisition
	On April 1, 2014, the Company acquired substantially all of the assets of EME.  EME, through its subsidiaries and affiliates, owned or leased and operated a portfolio of approximately 8,000 MW consisting of wind energy facilities and coal- and gas-fired generating facilities. The Company paid an aggregate purchase price of $3.5 billion, which was comprised of the following:
		Original Purchase Price			Purchase Price on Acquisition Date
	Cash and equivalents (a)	$	2,285		$	3,021
	Common shares (b)	350			401
	Liabilities acquired	—			71
	Total purchase price	2,635			3,493
	Less: cash acquired				1,422
	Net purchase price				$	2,071
	(a) The increase in cash paid relates to an increase in acquired cash on hand as well as changes in cash collateral, restricted cash and cash related to unconsolidated subsidiaries. It also reflects lease and debt payments in 2014.
	(b) The increase in the value of the common shares reflects an increase in trading price of NRG common shares between October 18, 2013 and April 1, 2014. The shares of NRG common stock were given a value of $350 million in determining the cash purchase price, which was based upon the volume-weighted average trading price over the 20 trading days prior to October 18, 2013.
	The purchase price was funded through the issuance of 12,671,977 shares of NRG common stock on April 1, 2014, the issuance of $700 million in newly-issued corporate debt, as described in Note 7, Debt and Capital Leases, and cash on hand. The Company also assumed non-recourse debt of approximately $1.2 billion.
	In connection with the transaction, NRG agreed to certain conditions with the parties to the Powerton and Joliet, or POJO, sale-leaseback transaction subject to which an NRG subsidiary assumed the POJO leveraged leases and NRG guaranteed the remaining payments under each lease, which total $485 million through 2034. In connection with this agreement, NRG has committed to fund up to $350 million in capital expenditures for plant modifications at Powerton and Joliet to comply with environmental regulations, as discussed further in Note 15, Environmental Matters. In addition, NRG assumed certain long-term contractual arrangements for fuel and transportation. Commitments under these arrangements totaled approximately $490 million.
	On April 30, 2014, subsequent to the acquisition, the Company acquired the remaining 50% ownership of Mission Del Sol LLC, which owns the Sunrise facility, a 586 MW natural gas facility in Fellows, California, from Chevron increasing the Company's ownership interest to 100% in exchange for the Company's 50% interest in six cogeneration facilities, previously co-owned with Chevron.
	The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The initial accounting for the business combination is not complete because the evaluation necessary to assess the fair values of certain net assets acquired is still in process. The provisional amounts are subject to revision until the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date. The allocation of the purchase price may be modified up to one year from the date of the acquisition as more information is obtained about the fair value of assets acquired and liabilities assumed. The purchase price of $3.5 billion was provisionally allocated as follows:
			(In millions)
	Assets
	Cash		$	1,422
	Current assets		676
	Property, plant and equipment		2,475
	Intangible assets		312
	Non-current assets		813
	Total assets acquired		5,698
	Liabilities
	Current and non-current liabilities		533
	Out-of-market contracts and leases		43
	Long-term debt		1,249
	Total liabilities assumed		1,825
	Less: noncontrolling interest		380
	Net assets acquired		$	3,493
	The Company incurred and expensed acquisition-related transaction costs of $14 million and $17 million for the three and six months ended June 30, 2014.
	Fair value measurements
	The provisional fair values of the property, plant and equipment, intangible assets and out-of-market contracts at the acquisition date were measured primarily based on significant inputs that are not observable in the market and thus represent a Level 3 measurement as defined in ASC 820. Significant inputs were as follows:
	Property, plant and equipment - The estimated fair values were determined primarily based on an income method using discounted cash flows and validated using a market approach based on recent transactions of comparable assets. The income approach was primarily relied upon as the forecasted cash flows more appropriately incorporate differences in regional markets, plant types, age, useful life, equipment condition and environmental controls of each asset. The income approach also allows for a more accurate reflection of current and expected market dynamics such as supply and demand, commodity prices and regulatory environment as of the acquisition date.
	Intangible assets - The fair values of the PPAs acquired were determined utilizing a variation of the income approach where the expected future cash flows resulting from the acquired PPAs were reduced by operating costs and charges for contributory assets and then discounted to present value at the weighted average cost of capital of an integrated utility peer group adjusted for project-specific financing attributes. The values were corroborated with available market data.
	Out-of-market lease contracts - The estimated fair values of the acquired leases were determined utilizing a variation of the income approach under which the fair value of the lease was determined by discounting the future lease payments at an appropriate discount rate and comparing it to the fair value of the property, plant and equipment being leased.
	Noncontrolling interest - The estimated fair value of the noncontrolling interests represent the fair value of the partners' contributions as of the acquisition date.
	Supplemental Pro Forma Information
	Since the acquisition date, EME contributed $311 million in operating revenues and $14 million in net losses attributable to NRG. The following supplemental pro forma information represents the results of operations as if NRG had acquired EME on January 1, 2013:
			For the six months ended							For the year ended
	(in millions except per share amounts)		30-Jun-14				30-Jun-13			31-Dec-13
	Operating revenues		$	7,655			$	5,618		$	12,598
	Net loss attributable to NRG Energy, Inc.		(136		)		(390		)	(1,009		)
	Loss per share attributable to NRG common stockholders:
	Basic		(0.41		)		(1.16		)	(3.00		)
	Diluted		(0.41		)		(1.16		)	(3.00		)
	The supplemental pro forma information has been adjusted to include the pro-forma impact of depreciation of property, plant and equipment, amortization of lease obligations and out-of-market contracts, based on the preliminary purchase price allocations. The pro forma data has also been adjusted to eliminate non-recurring transaction costs incurred by NRG, as well as the related tax impact. There were no transactions during the periods between NRG and EME. The pro forma results are presented for illustrative purposes only and do not reflect the realization of potential cost savings or any related integration costs. The Company expects to achieve certain cost savings from the acquisition; however, there can be no assurance that these cost savings will be achieved.
	2013 Acquisitions
	Energy Systems Acquisition
	On December 31, 2013, NRG Energy Center Omaha Holdings, LLC, an indirect wholly owned subsidiary of NRG Yield LLC, acquired 100% of Energy Systems Company, or Energy Systems, for approximately $120 million. The acquisition was financed from cash on hand. Energy Systems is an operator of steam and chilled thermal facilities that provides heating and cooling services to nonresidential customers in Omaha, Nebraska. The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The purchase price was primarily allocated to property, plant and equipment of $60 million, customer relationships of $59 million, and working capital of $1 million. The initial accounting for the business combination is not complete because the evaluations necessary to assess the fair values of certain net assets acquired and the amount of goodwill to be recognized are still in process. The provisional amounts are subject to revision until the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date.
	Gregory Acquisition
On August 7, 2013, NRG Texas Gregory, LLC, a wholly owned subsidiary of NRG, acquired Gregory Power Partners, L.P. for approximately $245 million in cash, net of $32 million cash acquired. Gregory is a cogeneration plant located in Corpus Christi, Texas, which has generation capacity of 388 MW and steam capacity of 160 MWt. The Gregory cogeneration plant provides steam, processed water and a small percentage of its electrical generation to the Corpus Christi Sherwin Alumina plant. The majority of the plant's generation is available for sale in the ERCOT market. The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The purchase price was provisionally allocated primarily to property, plant, and equipment of $248 million, current assets of $13 million, and other liabilities of $16 million. The accounting for the Gregory acquisition was completed as of June 30, 2014, at which point the provisional fair values became final with no material changes.

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2014
Fair Value of Financial Instruments Disclosure [Abstract]	'
Fair Value of Financial Instruments	'
	Fair Value of Financial Instruments
	This footnote should be read in conjunction with the complete description under Note 4, Fair Value of Financial Instruments, to the Company's 2013 Form 10-K.
	For cash and cash equivalents, funds deposited by counterparties, accounts and other receivables, accounts payable, restricted cash, and cash collateral paid and received in support of energy risk management activities, the carrying amount approximates fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy. The estimated carrying amounts and fair values of NRG's recorded financial instruments not carried at fair market value are as follows:
		As of June 30, 2014					As of December 31, 2013
		Carrying Amount		Fair Value			Carrying Amount			Fair Value
		(In millions)
	Assets:
	Notes receivable (a)	$	114	$	114		$	99		$	99
	Liabilities:
	Long-term debt, including current portion	18,988		19,576			16,804			17,222
	(a) Includes the current portion of notes receivable which is recorded in prepayments and other current assets on the Company's consolidated balance sheets.
	The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of debt securities, non publicly-traded long-term debt, and certain notes receivable of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy.
	Recurring Fair Value Measurements
	Debt securities, equity securities, and trust fund investments, which are comprised of various U.S. debt and equity securities, and derivative assets and liabilities, are carried at fair market value.
	The following tables present assets and liabilities measured and recorded at fair value on the Company's condensed consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:
		As of June 30, 2014
		Fair Value
	(In millions)	Level 1		Level 2			Level 3			Total
	Investment in available-for-sale securities (classified within other
	non-current assets):
	Debt securities	$	—	$	—		$	18		$	18
	Available-for-sale securities	14		—			—			14
	Other (a)	21		—			11			32
	Nuclear trust fund investments:
	Cash and cash equivalents	3		—			—			3
	U.S. government and federal agency obligations	37		4			—			41
	Federal agency mortgage-backed securities	—		62			—			62
	Commercial mortgage-backed securities	—		26			—			26
	Corporate debt securities	—		92			—			92
	Equity securities	292		—			58			350
	Foreign government fixed income securities	—		2			—			2
	Other trust fund investments:
	U.S. government and federal agency obligations	1		—			—			1
	Derivative assets:
	Commodity contracts	315		1,438			353			2,106
	Interest rate contracts	—		8			—			8
	Total assets	$	683	$	1,632		$	440		$	2,755
	Derivative liabilities:
	Commodity contracts	$	235	$	1,349		$	365		$	1,949
	Interest rate contracts	—		141			—			141
	Total liabilities	$	235	$	1,490		$	365		$	2,090
	(a) Primarily consists of mutual funds held in rabbi trusts for non-qualified deferred compensation plans for certain former employees.
		As of December 31, 2013
		Fair Value
	(In millions)	Level 1		Level 2			Level 3			Total
	Investment in available-for-sale securities (classified within other
	non-current assets):
	Debt securities	$	—	$	—		$	16		$	16
	Available-for-sale securities	2		—			—			2
	Other (a)	37		—			10			47
	Nuclear trust fund investments:
	Cash and cash equivalents	26		—			—			26
	U.S. government and federal agency obligations	40		5			—			45
	Federal agency mortgage-backed securities	—		62			—			62
	Commercial mortgage-backed securities	—		14			—			14
	Corporate debt securities	—		70			—			70
	Equity securities	276		—			56			332
	Foreign government fixed income securities	—		2			—			2
	Other trust fund investments:
	U.S. government and federal agency obligations	1		—			—			1
	Derivative assets:
	Commodity contracts	346		1,126			147			1,619
	Interest rate contracts	—		20			—			20
Total assets	$	728	$	1,299		$	229		$	2,256
Derivative liabilities:
Commodity contracts	$	216	$	831		$	134		$	1,181
Interest rate contracts	—		69			—			69
Total liabilities	$	216	$	900		$	134		$	1,250
(a) Primarily consists of mutual funds held in rabbi trusts for non-qualified deferred compensation plans for certain former employees.
There were no transfers during the three and six months ended June 30, 2014 and 2013 between Levels 1 and 2. The following tables reconcile, for the three and six months ended June 30, 2014 and 2013, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements, at least annually, using significant unobservable inputs:
	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Three months ended June 30, 2014														Six months ended June 30, 2014
(In millions)	Debt Securities		Other			Trust Fund Investments			Derivatives(a)			Total			Debt Securities		Other			Trust Fund Investments			Derivatives(a)			Total
Beginning balance	$	18	$	11		$	56		$	23		$	108		$	16	$	10		$	56		$	13		$	95
Total gains/(losses) — realized/unrealized:
Included in earnings	—		—			—			(12		)	(12		)	—		1			—			4			5
Included in OCI	—		—			—			—			—			2		—			—			—			2
Included in nuclear	—		—			1			—			1			—		—			1			—			1
decom-
missioning
obligation
Purchases	—		—			1			(63		)	(62		)	—		—			1			(84		)	(83		)
Contracts acquired in Dominion and EME acquisition	—		—			—			36			36			—		—			—			39			39
Transfers into Level 3 (b)	—		—			—			—			—			—		—			—			18			18
Transfers out of Level 3 (b)	—		—			—			4			4			—		—			—			(2		)	(2		)
Ending balance as of June 30, 2014	$	18	$	11		$	58		$	(12	)	$	75		$	18	$	11		$	58		$	(12	)	$	75
Gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of June 30, 2014	$	—	$	—		$	—		$	2		$	2		$	—	$	—		$	—		$	21		$	21
(a)	Consists of derivative assets and liabilities, net.
(b)	Transfers in/out of Level 3 are related to the availability of external broker quotes and are valued as of the end of the reporting period. All transfers in/out are with Level 2.
	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Three months ended June 30, 2013											Six months ended June 30, 2013
(In millions)	Debt Securities		Trust Fund Investments			Derivatives(a)			Total			Debt Securities			Trust Fund Investments		Derivatives(a)			Total
Beginning balance	$	13	$	50		$	5		$	68		$	12		$	47	$	(12	)	$	47
Total (losses)/gains — realized/unrealized:
Included in earnings	—		—			9			9			—			—		(18		)	(18		)
Included in OCI	2		—			—			2			3			—		—			3
Included in nuclear decom-	—		(1		)	—			(1		)	—			2		—			2
missioning obligations
Purchases	—		1			(6		)	(5		)	—			1		(7		)	(6		)
Transfers into Level 3 (b)	—		—			12			12			—			—		27			27
Transfers out of Level 3 (b)	—		—			(32		)	(32		)	—			—		(2		)	(2		)
Ending balance as of June 30, 2013	$	15	$	50		$	(12	)	$	53		$	15		$	50	$	(12	)	$	53
Gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of June 30, 2013	—		—			24			24			—			—		3			3
(a)	Consists of derivative assets and liabilities, net.
(b)	Transfers in/out of Level 3 are related to the availability of external broker quotes and are valued as of the end of the reporting period. All transfers in/out are with Level 2.
Realized and unrealized gains and losses included in earnings that are related to energy derivatives are recorded in operating revenues and cost of operations.
Derivative Fair Value Measurements
A portion of NRG's contracts are exchange-traded contracts with readily available quoted market prices. A majority of NRG's contracts are non-exchange-traded contracts valued using prices provided by external sources, primarily price quotations available through brokers or over-the-counter and on-line exchanges. The remainder of the assets and liabilities represent contracts for which external sources or observable market quotes are not available for the whole term or for certain delivery months or the contracts are retail and load following power contracts. These contracts are valued using various valuation techniques including but not limited to internal models that apply fundamental analysis of the market and corroboration with similar markets. As of June 30, 2014, contracts valued with prices provided by models and other valuation techniques make up 17% of the total derivative assets and 17% of the total derivative liabilities.
The fair value of each contract is discounted using a risk free interest rate. In addition, the Company applies a credit reserve to reflect credit risk which is calculated based on published default probabilities. As of June 30, 2014, the credit reserve resulted in a $1 million increase in fair value which is a gain in OCI. As of June 30, 2013, the credit reserve resulted in a $1 million decrease in fair value which is composed of a $2 million gain in OCI and a $3 million loss in operating revenue and cost of operations.
Concentration of Credit Risk
In addition to the credit risk discussion as disclosed in Note 2, Summary of Significant Accounting Policies, to the Company's 2013 Form 10-K, the following is a discussion of the concentration of credit risk for the Company's contractual obligations. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. NRG is exposed to counterparty credit risk through various activities including wholesale sales, fuel purchases and retail supply arrangements, and retail customer credit risk through its retail load activities.
Counterparty Credit Risk
The Company's counterparty credit risk policies are disclosed in its 2013 Form 10-K. As of June 30, 2014, counterparty credit exposure, excluding credit risk exposure under certain long term agreements, was $742 million and NRG held collateral (cash and letters of credit) against those positions of $12 million, resulting in a net exposure of $740 million. Approximately 85% of the Company's exposure before collateral is expected to roll off by the end of 2015. Counterparty credit exposure is valued through observable market quotes and discounted at a risk free interest rate. The following tables highlight net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market and NPNS, and non-derivative transactions. The exposure is shown net of collateral held, and includes amounts net of receivables or payables.
	Net Exposure (a)
Category	(% of Total)
Financial institutions	34	%
Utilities, energy merchants, marketers and other	31
ISOs	30
Coal and emissions	5
Total as of June 30, 2014	100	%
	Net Exposure (a)
Category	(% of Total)
Investment grade	90	%
Non-rated (b)	6
Non-investment grade	4
Total as of June 30, 2014	100	%
(a)	Counterparty credit exposure excludes uranium and coal transportation contracts because of the unavailability of market prices.
(b)	For non-rated counterparties, a significant portion are related to ISO and municipal public power entities, which are considered investment grade equivalent ratings based on NRG's internal credit ratings.
NRG has counterparty credit risk exposure to certain counterparties, each of which represent more than 10% of total net exposure discussed above. The aggregate of such counterparties' exposure was $149 million. Changes in hedge positions and market prices will affect credit exposure and counterparty concentration. Given the credit quality, diversification and term of the exposure in the portfolio, NRG does not anticipate a material impact on the Company's financial position or results of operations from nonperformance by any of NRG's counterparties.
Counterparty credit exposure described above excludes credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations, and solar PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates its credit exposure for these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of June 30, 2014, aggregate credit risk exposure managed by NRG to these counterparties was approximately $3.5 billion, including $1.1 billion related to assets of NRG Yield, Inc., for the next five years. The majority of these power contracts are with utilities or public power entities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations, which NRG is unable to predict.
Retail Customer Credit Risk
NRG is exposed to retail credit risk through the Company's retail electricity providers, which serve commercial, industrial and governmental/institutional customers and the Mass market. Retail credit risk results when a customer fails to pay for products or services rendered. The losses may result from both nonpayment of customer accounts receivable and the loss of in-the-money forward value. NRG manages retail credit risk through the use of established credit policies that include monitoring of the portfolio, and the use of credit mitigation measures such as deposits or prepayment arrangements.
As of June 30, 2014, the Company believes its retail customer credit exposure was diversified across many customers and various industries, as well as government entities.

Nuclear_Decommissioning_Trust_

Nuclear Decommissioning Trust Fund	6 Months Ended
	Jun. 30, 2014
Nuclear Decommissioning Trust Fund Disclosure [Abstract]	'
Nuclear Decommissioning Trust Fund	'
	Nuclear Decommissioning Trust Fund
	This footnote should be read in conjunction with the complete description under Note 6, Nuclear Decommissioning Trust Fund, to the Company's 2013 Form 10-K.
	NRG's Nuclear Decommissioning Trust Fund assets are comprised of securities classified as available-for-sale and recorded at fair value based on actively quoted market prices. NRG accounts for the Nuclear Decommissioning Trust Fund in accordance with ASC 980, Regulated Operations, because the Company's nuclear decommissioning activities are subject to approval by the PUCT with regulated rates that are designed to recover all decommissioning costs and that can be charged to and collected from the ratepayers per PUCT mandate. Since the Company is in compliance with PUCT rules and regulations regarding decommissioning trusts and the cost of decommissioning is the responsibility of the Texas ratepayers, not NRG, all realized and unrealized gains or losses (including other-than-temporary impairments) related to the Nuclear Decommissioning Trust Fund are recorded to nuclear decommissioning trust liability and are not included in net income or accumulated other comprehensive income, consistent with regulatory treatment.
	The following table summarizes the aggregate fair values and unrealized gains and losses (including other-than-temporary impairments) for the securities held in the trust funds, as well as information about the contractual maturities of those securities.
		As of June 30, 2014							As of December 31, 2013
	(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted-average Maturities (In years)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted-average Maturities (In years)
	Cash and cash equivalents	$	3	$	—	$	—	—	$	26	$	—	$	—	—
	U.S. government and federal agency obligations	41		2		—		9	45		1		1		9
	Federal agency mortgage-backed securities	62		1		1		25	62		1		1		24
	Commercial mortgage-backed securities	26		—		—		30	14		—		—		29
	Corporate debt securities	92		3		—		11	70		1		1		9
	Equity securities	350		219		—		—	332		204		—		—
	Foreign government fixed income securities	2		—		—		16	2		—		—		9
	Total	$	576	$	225	$	1		$	551	$	207	$	3
	The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from these sales. The cost of securities sold is determined on the specific identification method.
		Six months ended June 30,
		2014		2013
		(In millions)
	Realized gains	$	7	$	3
	Realized losses	3		4
	Proceeds from sale of securities	334		208

Accounting_for_Derivative_Inst

Accounting for Derivative Instruments and Hedging Activities	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Accounting for Derivative Instruments and Hedging Activities	'
	Accounting for Derivative Instruments and Hedging Activities
	This footnote should be read in conjunction with the complete description under Note 5, Accounting for Derivative Instruments and Hedging Activities, to the Company's 2013 Form 10-K.
	Energy-Related Commodities
	As of June 30, 2014, NRG had energy-related derivative financial instruments extending through 2019. The Company voluntarily de-designated all remaining commodity cash flow hedges as of January 1, 2014, and prospectively marked these derivatives to market through the income statement.
	Interest Rate Swaps
	NRG is exposed to changes in interest rates through the Company's issuance of variable and fixed rate debt. In order to manage the Company's interest rate risk, NRG enters into interest rate swap agreements. As of June 30, 2014, the Company had interest rate derivative instruments on non-recourse debt extending through 2032, the majority of which are designated as cash flow hedges.
	Volumetric Underlying Derivative Transactions
	The following table summarizes the net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity, excluding those derivatives that qualified for the NPNS exception as of June 30, 2014 and December 31, 2013. Option contracts are reflected using delta volume. Delta volume equals the notional volume of an option adjusted for the probability that the option will be in-the-money at its expiration date.
			Total Volume
			June 30, 2014				December 31, 2013
	Commodity	Units	(In millions)
	Emissions	Short Ton	1				—
	Coal	Short Ton	70				51
	Natural Gas	MMBtu	(239		)		(166		)
	Oil	Barrel	—				1
	Power	MWh	(43		)		(27		)
	Interest	Dollars	$	2,569			$	1,444
	The increase in the natural gas position was the result of additional strategic hedges entered into during the year, partially offset by the settlement of positions during the period. The increase in the interest rate swap position was primarily the result of interest rate swaps acquired in connection with EME.
	Fair Value of Derivative Instruments
	The following table summarizes the fair value within the derivative instrument valuation on the balance sheets:
		Fair Value
		Derivative Assets								Derivative Liabilities
		June 30, 2014				December 31, 2013				June 30, 2014				December 31, 2013
		(In millions)
	Derivatives designated as cash flow hedges:
	Interest rate contracts current	$	—			$	—			$	59			$	35
	Interest rate contracts long-term	7				14				74				29
	Commodity contracts current	—				—				—				1
	Commodity contracts long-term	—				—				—				1
	Total derivatives designated as cash flow hedges	7				14				133				66
	Derivatives not designated as cash flow hedges:
	Interest rate contracts current	—				—				5				4
	Interest rate contracts long-term	1				6				3				1
	Commodity contracts current	1,701				1,328				1,672				1,015
	Commodity contracts long-term	405				291				277				164
	Total derivatives not designated as cash flow hedges	2,107				1,625				1,957				1,184
	Total derivatives	$	2,114			$	1,639			$	2,090			$	1,250
	The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. In addition, collateral received or paid on the Company's derivative assets or liabilities are recorded on a separate line item on the balance sheet. The following table summarizes the offsetting of derivatives by counterparty master agreement level and collateral received or paid:
			Gross Amounts Not Offset in the Statement of Financial Position
			Gross Amounts of Recognized Assets / Liabilities				Derivative Instruments				Cash Collateral (Held) / Posted				Net Amount
	As of June 30, 2014		(In millions)
	Commodity contracts:
	Derivative assets		$	2,106			$	(1,706	)		$	(4	)		$	396
	Derivative liabilities		(1,949		)		1,706				75				(168		)
	Total commodity contracts		157				—				71				228
	Interest rate contracts:
	Derivative assets		8				(6		)		—				2
	Derivative liabilities		(141		)		6				—				(135		)
	Total interest rate contracts		(133		)		—				—				(133		)
	Total derivative instruments		$	24			$	—			$	71			$	95
			Gross Amounts Not Offset in the Statement of Financial Position
			Gross Amounts of Recognized Assets / Liabilities				Derivative Instruments				Cash Collateral (Held) / Posted				Net Amount
	As of December 31, 2013		(In millions)
	Commodity contracts:
	Derivative assets		$	1,619			$	(1,032	)		$	(62	)		$	525
	Derivative liabilities		(1,181		)		1,032				18				(131		)
	Total commodity contracts		438				—				(44		)		394
	Interest rate contracts:
	Derivative assets		20				(12		)		—				8
	Derivative liabilities		(69		)		12				—				(57		)
	Total interest rate contracts		(49		)		—				—				(49		)
	Total derivative instruments		$	389			$	—			$	(44	)		$	345
	Accumulated Other Comprehensive Loss
The following table summarizes the effects of ASC 815 on the Company's accumulated OCI balance attributable to cash flow hedge derivatives, net of tax:
	Three months ended June 30, 2014												Six months ended June 30, 2014
	Energy Commodities				Interest Rate				Total				Energy Commodities				Interest Rate			Total
	(In millions)
Accumulated OCI beginning balance	$	(1	)		$	(31	)		$	(32	)		$	(1	)		$	(22	)	$	(23	)
Reclassified from accumulated OCI to income:
Due to realization of previously deferred amounts	—				(7		)		(7		)		—				(8		)	(8		)
Mark-to-market of cash flow hedge accounting contracts	—				(12		)		(12		)		—				(20		)	(20		)
Accumulated OCI ending balance, net of $29 tax	$	(1	)		$	(50	)		$	(51	)		$	(1	)		$	(50	)	$	(51	)
Losses expected to be realized from OCI during the next 12 months, net of $7 tax	$	(1	)		$	(12	)		$	(13	)		$	(1	)		$	(12	)	$	(13	)
	Three months ended June 30, 2013												Six months ended June 30, 2013
	Energy Commodities				Interest Rate				Total				Energy Commodities				Interest Rate			Total
	(In millions)
Accumulated OCI beginning balance	$	42			$	(66	)		$	(24	)		$	41			$	(72	)	$	(31	)
Reclassified from accumulated OCI to income:
Due to realization of previously deferred amounts	(15		)		1				(14		)		(23		)		4			(19		)
Mark-to-market of cash flow hedge accounting contracts	(3		)		34				31				6				37			43
Accumulated OCI ending balance, net of $4 tax	$	24			$	(31	)		$	(7	)		$	24			$	(31	)	$	(7	)
Gains/(losses) expected to be realized from OCI during the next 12 months, net of $10 tax	$	26			$	(9	)		$	17			$	26			$	(9	)	$	17
Losses recognized in income from the ineffective portion of cash flow hedges	$	—			$	(1	)		$	(1	)		$	(1	)		$	—		$	(1	)
Amounts reclassified from accumulated OCI into income and amounts recognized in income from the ineffective portion of cash flow hedges are recorded to operating revenue for commodity contracts and interest expense for interest rate contracts. There was no ineffectiveness for the three or six months ended June 30, 2014.
Impact of Derivative Instruments on the Statements of Operations
Unrealized gains and losses associated with changes in the fair value of derivative instruments not accounted for as cash flow hedges and ineffectiveness of hedge derivatives are reflected in current period earnings.
The following table summarizes the pre-tax effects of economic hedges that have not been designated as cash flow hedges, ineffectiveness on cash flow hedges and trading activity on the Company's statement of operations. The effect of commodity hedges is included within operating revenues and cost of operations and the effect of interest rate hedges is included in interest expense.
	Three months ended June 30,								Six months ended June 30,
	2014				2013				2014				2013
Unrealized mark-to-market results	(In millions)
Reversal of previously recognized unrealized gains on settled positions related to economic hedges	$	(5	)		$	(7	)		$	(2	)		$	(32	)
Reversal of gain positions acquired as part of the GenOn and EME acquisitions	(84		)		(99		)		(162		)		(187		)
Net unrealized (losses)/gains on open positions related to economic hedges	(30		)		204				(223		)		55
Losses on ineffectiveness associated with open positions treated as cash flow hedges	—				—				—				(1		)
Total unrealized mark-to-market (losses)/gains for economic hedging activities	(119		)		98				(387		)		(165		)
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	5				(1		)		5				(29		)
Reversal of (gain)/loss positions acquired as part of the GenOn and EME acquisitions	(19		)		2				(20		)		—
Net unrealized gains/(losses) on open positions related to trading activity	14				(13		)		30				(26		)
Total unrealized mark-to-market (losses)/gains for trading activity	—				(12		)		15				(55		)
Total unrealized (losses)/gains	$	(119	)		$	86			$	(372	)		$	(220	)
	Three months ended June 30,								Six months ended June 30,
	2014				2013				2014				2013
	(In millions)
Unrealized (losses)/gains included in operating revenues	$	(48	)		$	181			$	(364	)		(340		)
Unrealized (losses)/gains included in cost of operations	(71		)		(95		)		(8		)		120
Total impact to statement of operations — energy commodities	$	(119	)		$	86			$	(372	)		$	(220	)
Total impact to statement of operations — interest rate contracts	$	(3	)		$	4			$	(7	)		$	6
The reversal of gain or loss positions acquired as part of the GenOn and EME acquisitions were valued based upon the forward prices on the acquisition dates.
For the six months ended June 30, 2014, the unrealized loss from open economic hedge positions was primarily the result of a decrease in value of forward purchases due to decreases in ERCOT heat rates combined with a decrease in value of forward sales of natural gas and electricity due to increases in East power and natural gas prices.
For the six months ended June 30, 2013, the unrealized gain from open economic hedge positions was primarily the result of an increase in value of forward purchases due to decreases in ERCOT heat rates combined with a decrease in the value of forward sales of natural gas and electricity due to a decrease in forward natural gas and electricity prices.
As of June 30, 2013, NRG had interest rate swaps designated as cash flow hedges on the CVSR solar project. The notional amount on the swaps exceeded the actual debt draws on the project. As such, NRG discontinued cash flow hedge accounting for these contracts and $5 million of loss previously deferred in OCI was recognized in earnings for the three and six months ended June 30, 2013.
Credit Risk Related Contingent Features
Certain of the Company's hedging agreements contain provisions that require the Company to post additional collateral if the counterparty determines that there has been deterioration in credit quality, generally termed “adequate assurance” under the agreements, or requires the Company to post additional collateral if there were a one notch downgrade in the Company's credit rating. The collateral required for contracts with adequate assurance clauses that are in a net liability position as of June 30, 2014 was $71 million. The Company is also a party to certain marginable agreements where NRG has a net liability position, but the counterparty has not called for the collateral due, which was approximately $22 million as of June 30, 2014.
See Note 4, Fair Value of Financial Instruments, to this Form 10-Q for discussion regarding concentration of credit risk.

Debt_and_Capital_Leases

Debt and Capital Leases	6 Months Ended
	Jun. 30, 2014
Long Term Debt Disclosure [Abstract]	'
Debt and Capital Leases	'
	Debt and Capital Leases
	This footnote should be read in conjunction with the complete description under Note 12, Debt and Capital Leases, to the Company's 2013 Form 10-K. Long-term debt and capital leases consisted of the following:
	(In millions, except rates)	June 30, 2014			December 31, 2013			Current interest rate % (a)
	Recourse debt:
	Senior notes, due 2018	$	1,130		$	1,130		7.625
	Senior notes, due 2019	—			800			7.625
	Senior notes, due 2019	223			602			8.5
	Senior notes, due 2020	1,063			1,062			8.25
	Senior notes, due 2021	1,128			1,128			7.875
	Senior notes, due 2022	1,100			—			6.25
	Senior notes, due 2023	990			990			6.625
	Senior notes, due 2024	1,000			—			6.25
	Term loan facility, due 2018	1,992			2,002			L+2.00
	Indian River Power LLC, tax-exempt bonds, due 2040 and 2045	247			247			5.375 - 6.00
	Dunkirk Power LLC, tax-exempt bonds, due 2042	59			59			5.875
	Fort Bend County, tax-exempt bonds, due 2038, 2042, and 2045	67			67			4.75
	Subtotal NRG recourse debt	8,999			8,087
	Non-recourse debt:
	GenOn senior notes, due 2017	774			782			7.875
	GenOn senior notes, due 2018	769			780			9.5
	GenOn senior notes, due 2020	616			621			9.875
	GenOn Americas Generation senior notes, due 2021	499			503			8.5
	GenOn Americas Generation senior notes, due 2031	434			435			9.125
	Subtotal GenOn debt (non-recourse to NRG)	3,092			3,121
	NRG Marsh Landing, due 2017 and 2023	464			473			L+2.75 - 3.00
	NRG Energy Center Minneapolis LLC, due 2017 and 2025	124			127			5.95 - 7.25
	NRG Solar Alpine LLC, due 2022	170			221			L+2.50/L+1.75
	NRG Solar Borrego I LLC, due 2024 and 2038	77			78			L+2.50/5.65
	NRG West Holdings LLC, due 2023	520			512			L+2.50 - 2.875
	NRG Yield Inc. Convertible Senior Notes, due 2019	324			—			3.5
	NRG Yield - other	320			372			various
	Subtotal NRG Yield debt (non-recourse to NRG)	1,999			1,783
	CVSR High Plains Ranch II LLC, due 2037	798			1,104			2.339 - 3.775
	Agua Caliente Solar LLC, due 2037	923			878			2.395 - 3.633
	Ivanpah Financing, due 2014, 2015, 2033 and 2038	1,595			1,575			0.437 - 4.256
	NRG Peaker Finance Co. LLC, bonds due 2019	128			154			L+1.07
	Tapestry Wind LLC, due 2021	196			—			L+2.50
	Walnut Creek, term loans due 2023	409			—			L+2.25
	Viento Funding II, Inc., due 2023	198			—			L+2.75
	Cedro Hill Wind LLC, due 2025	113			—			L+3.125
	NRG - other	538			102			various
	Subtotal NRG non-recourse debt	4,898			3,813
	Subtotal non-recourse debt (including GenOn and NRG Yield)	9,989			8,717
	Subtotal long-term debt (including current maturities)	18,988			16,804
	Capital leases:
	Chalk Point capital lease, due 2015	7			10			8.19
	Other	3			3			various
	Subtotal long-term debt and capital leases (including current maturities)	18,998			16,817
	Less current maturities	833			1,050
	Total long-term debt and capital leases	$	18,165		$	15,767
	(a) As of June 30, 2014, L+ equals 3 month LIBOR plus x%, with the exception of the NRG Solar Kansas South LLC and Viento Funding II term loan which is 6 month LIBOR plus x%.
	NRG Recourse Debt
	Senior Notes
	Issuance of 2024 Senior Notes
	On April 21, 2014, NRG issued $1.0 billion in aggregate principal amount at par of 6.25% senior notes due 2024. The notes are senior unsecured obligations of NRG and are guaranteed by certain of its subsidiaries. Interest is payable semi-annually beginning on November 1, 2014, until the maturity date of May 1, 2024. A portion of the cash proceeds were used to redeem all remaining of its 7.625% 2019 Senior Notes, and the rest of the proceeds are expected to be used to redeem all remaining $225 million of its 8.5% 2019 Senior Notes in September 2014, as discussed below.
	In connection with the 2024 Senior Notes, NRG entered into a registration payment arrangement. Failure to file a registration statement relating to the 2024 Senior Notes by January 29, 2015 will result in a registration default. For the first 90-day period immediately following a registration default, additional interest will be paid in an amount equal to 0.25% per annum of the principal amount of 2024 Senior Notes outstanding, as applicable. The amount of interest paid will increase by an additional 0.25% per annum with respect to each subsequent 90-day period until all registration defaults are cured, up to a maximum amount of interest of 1.0% per annum of the principal amount of the 2024 Senior Notes outstanding, as applicable. The additional interest is paid on the next scheduled interest payment date and following the cure of the registration default, the additional interest payment will cease.
	Issuance of 2022 Senior Notes
	On January 27, 2014, NRG issued $1.1 billion in aggregate principal amount at par of 6.25% senior notes due 2022. The notes are senior unsecured obligations of NRG and are guaranteed by certain of its subsidiaries. Interest is payable semi-annually beginning on July 15, 2014, until the maturity date of July 15, 2022. The proceeds were utilized to redeem the 8.5% and 7.625% 2019 Senior Notes, as described below, and to fund the acquisition of EME, as further described in Note 3, Business Acquisitions and Dispositions.
	In connection with the 2022 Senior Notes, NRG entered into a registration payment arrangement. Failure to file a registration statement relating to the 2022 Senior Notes by November 6, 2014 will result in a registration default. For the first 90-day period immediately following a registration default, additional interest will be paid in an amount equal to 0.25% per annum of the principal amount of 2022 Senior Notes outstanding, as applicable. The amount of interest paid will increase by an additional 0.25% per annum with respect to each subsequent 90-day period until all registration defaults are cured, up to a maximum amount of interest of 1.0% per annum of the principal amount of the 2022 Senior Notes outstanding, as applicable. The additional interest is paid on the next scheduled interest payment date and following the cure of the registration default, the additional interest payment will cease.
	Redemptions of 8.5% and 7.625% 2019 Senior Notes
	On February 10, 2014, the Company redeemed $308 million of its 8.5% 2019 Senior Notes and $91 million of its 7.625% 2019 Senior Notes through a tender offer, at an average early redemption percentage of 106.992% and 105.500%, respectively. A $33 million loss on debt extinguishment of the 8.5% and 7.625% 2019 Senior Notes was recorded during the three months ended March 31, 2014, primarily consisting of the premiums paid on the redemption and the write-off of previously deferred financing costs.
	On April 21, 2014, the Company redeemed $74 million of its 8.5% 2019 Senior Notes and $337 million of its 7.625% 2019 Senior Notes through a tender offer and call, at an average early redemption percentage of 105.250% and 104.200%, respectively. A $22 million loss on debt extinguishment of the 8.5% and 7.625% 2019 Senior Notes was recorded during the three months ended June 30, 2014, primarily consisting of the premiums paid on the redemption and the write-off of previously deferred financing costs.
	On May 21, 2014, NRG redeemed for cash all of its remaining 7.625% 2019 Senior Notes at an average early redemption percentage of 103.813%. A $18 million loss on debt extinguishment of the 7.625% 2019 Senior Notes was recorded during the three months ended June 30, 2014, primarily consisting of the premiums paid on the redemption and the write-off of previously deferred financing costs.
On August 4, 2014, the Company announced that it gave the required notice under the governing indenture to redeem for cash all of its remaining 8.5% 2019 Senior Notes on September 3, 2014, at an average early redemption percentage of 104.25%.
Senior Credit Facility
On June 4, 2013, NRG amended the Term Loan Facility to (i) obtain additional financing of $450 million, which was issued at a discount of 99.5%; and (ii) adjust the interest rate from LIBOR plus 2.50% to LIBOR plus 2.00%. In addition, the Company redeemed and re-issued $407 million of the Term Loan Facility to new lenders resulting in a $7 million loss on debt extinguishment, recorded during the three months ended June 30, 2013, which primarily consisted of the write-off of previously deferred financing costs and unamortized discount. The proceeds from the additional $450 million borrowed were used for general corporate purposes, including the redemption of the 2014 GenOn Senior Notes. Debt issuance costs of $23 million and a discount on debt issuance of $4 million will be amortized to interest expense through the maturity date of the Term Loan Facility.
The Company also amended the Revolving Credit Facility to (i) increase the capacity by $211 million to a total of $2.5 billion; (ii) adjust the interest rate to LIBOR plus 2.25%; and (iii) extend the maturity date to July 1, 2018 to coincide with the maturity date of the Term Loan Facility. As a result of the amended Revolving Credit Facility, the Company capitalized debt issuance costs of $4 million, which will be amortized to interest expense through the maturity date of the Revolving Credit Facility. A $3 million loss on debt extinguishment was recorded during the three months ended June 30, 2013 related to the write-off of previously deferred financing costs.
Senior Notes Repurchases
On December 17, 2012, NRG entered into an agreement with a financial institution to repurchase up to $200 million of the Senior Notes in the open market by February 27, 2013.  In the first quarter of 2013, the Company paid $80 million, $104 million, and $42 million, at an average price of 114.179%, 111.700%, and 113.082% of face value, for repurchases of the Company's 2018 Senior Notes, 2019 Senior Notes and 2020 Senior Notes, respectively. A $28 million loss on the debt extinguishment of the 2018 Senior Notes, 2019 Senior Notes and 2020 Senior Notes was recorded during the three months ended March 31, 2013 which primarily consisted of the premiums paid on the repurchases and the write-off of previously deferred financing costs.
NRG Non-Recourse Debt
The Company has non-recourse debt that is secured by acquired or developed projects that are held in several of its subsidiaries.  In the event of a bankruptcy, receivership, liquidation or similar event involving a subsidiary, the assets of such subsidiary would be used first to satisfy claims of creditors of the subsidiary, including liabilities under the non-recourse debt associated with such subsidiaries, rather than the creditors of NRG.
Ivanpah Financing — Cash Grant Bridge Loans
On June 24, 2014, Solar Partners I received an extension with respect to its borrowings under the Ivanpah Credit Agreement previously due on June 27, 2014, which are subsequently due December 27, 2014. On February 27, 2014, Solar Partners II received an extension with respect to its borrowings previously due in 2014, which are subsequently due in February 2015. The borrowings of Solar Partners VIII are due in October 2014. Solar Partners I, Solar Partners II, and Solar Partners VIII submitted applications to the U.S. Department of Treasury for cash grants; any proceeds received will be utilized to repay the borrowings.
Redemption of GenOn Senior Notes
In June 2013, the Company redeemed all of the 2014 GenOn Senior Notes with an aggregate outstanding principal amount of $575 million at a redemption price of 106.778% of face value as well as any accrued and unpaid interest as of the redemption date. In connection with the redemption, an $11 million loss on the debt extinguishment of the 2014 GenOn Senior Notes was recorded during the three months ended June 30, 2013 which primarily consisted of a make whole premium payment offset by the write-off of unamortized premium.
EME Project Financings
The following table summarizes the terms of the significant non-recourse project level debt assumed by NRG in the EME acquisition:
Amount in millions, except rates	Term Loan Facility						Letter of Credit Facility				Bond Facility
Non-Recourse Debt	Amount Outstanding as of June 30, 2014			Interest Rate		Maturity Date	Amount Outstanding as of June 30, 2014		Interest Rate	Maturity Date	Amount Outstanding as of June 30, 2014		Interest Rate	Maturity Date
Broken Bow Wind	$	49		3-Month LIBOR + 2.875%		12/31/27	$	—	—	—	$	—	—	—
Cedro Hill Wind	113			3-Month LIBOR + 3.125%		12/31/25	—		—	—	—		—	—
Crofton Bluffs	25			3-Month LIBOR + 2.875%		12/31/27	—		—	—	—		—	—
Laredo Ridge Wind	67			3-Month LIBOR + 2.875%		3/31/26	—		—	—	—		—	—
Tapestry Wind	196			3-Month LIBOR + 2.500%		12/21/21	20		2.50%	12/21/21	—		—	—
Viento Funding II	198			6-Month LIBOR + 2.750%		7/11/23	27		2.75%	7/11/20	—		—	—
Walnut Creek Energy	409			3-Month LIBOR + 2.250%		5/31/23	60		2.00%	5/17/23	—		—	—
WCEP Holding LLC	53			3-Month LIBOR + 4.000%		5/31/23	—		—	—	—		—	—
American Bituminous	—			—		—	38		2.65%	11/7/14	36		0.06%/ Weekly per SIFMA rate(a)	10/1/17
High Lonesome Mesa	—			—		—	—		—	—	62		6.85%	11/1/17
Various	15			various		various	52		various	various	—		—	—
Total	$	1,125					$	197			$	98
(a) Securities Industry and Financial Markets Association, or SIFMA
Interest Rate Swaps — EME Project Financings
Many of EME's project subsidiaries entered into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. These swaps amortize in proportion to their respective loans and are floating for fixed where the project subsidiary pays its counterparty the equivalent of a fixed interest payment on a predetermined notional value and will receive quarterly the equivalent of a floating interest payment based on the same notional value. All interest rate swap payments by the project subsidiary and its counterparty are made quarterly and the LIBOR is determined in advance of each interest period. The following table summarizes the swaps related to EME's project level debt as of June 30, 2014.
Non-Recourse Debt	% of Principal		Fixed Interest Rate			Floating Interest Rate	Notional Amount at June 30, 2014		Effective Date	Maturity Date
							(In millions)
Walnut Creek Energy	90	%	3.543	%		3-Month LIBOR	$	368	28-Jun-13	31-May-23
WCEP Holdings	90	%	4.003	%		3-Month LIBOR	48		28-Jun-13	31-May-23
Viento Funding II	90	%	various			6-Month LIBOR	179		various	various
Viento Funding II	90	%	4.985	%		6-Month LIBOR	63		July 11, 2023	June 30, 2028
Cedro Hill	90	%	4.29	%		3-Month LIBOR	102		December 31, 2010	December 31, 2025
Laredo Ridge	90	%	3.46	%		3-Month LIBOR	60		March 31, 2011	March 31, 2026
Tapestry	90	%	2.21	%		3-Month LIBOR	176		December 30, 2011	December 21, 2021
Tapestry	75	%	3.57	%		3-Month LIBOR	60		December 21, 2021	December 21, 2029
Broken Bow	90	%	2.96	%		3-Month LIBOR	44		December 31, 2013	December 31, 2027
Crofton Bluffs	90	%	2.748	%		3-Month LIBOR	23		December 31, 2013	December 31, 2027
Total							$	1,123
High Lonesome Mesa Facility
Prior to the Company's acquisition of EME, an intercompany tax credit agreement related to the High Lonesome Mesa facility was terminated. The termination was a default under a project financing arrangement that, after the closing of the acquisition, ripened into an event of default. As a result, the balance under the project financing arrangement is classified as current and the lender can request repayment at any time. The facility is secured by the assets of High Lonesome Mesa and is non-recourse to NRG.
NRG Yield Operating LLC Senior Notes
On August 5, 2014, Yield Operating issued $500 million of senior unsecured notes with the intention of utilizing the proceeds to fund the acquisition of the Alta Wind Assets. The Yield Operating senior notes bear interest at 5.375% and mature in August 2024. Interest on the notes is payable semi-annually on February 15 and August 15 of each year, commencing on February 15, 2015. The notes are senior unsecured obligations of Yield Operating and will be guaranteed by NRG Yield LLC, Yield Operating’s parent company, and by certain of Yield Operating’s wholly owned current and future subsidiaries.
NRG Yield, Inc. Convertible Notes
During the first quarter of 2014, NRG Yield, Inc. closed on its offering of $345 million aggregate principal amount of 3.50% Convertible Senior Notes due 2019, or the NRG Yield Convertible Notes. The NRG Yield Convertible Notes are convertible, under certain circumstances, into NRG Yield, Inc. Class A common stock, cash or a combination thereof at an initial conversion price of $46.55 per Class A common share, which is equivalent to an initial conversion rate of approximately 21.4822 shares of Class A common stock per $1,000 principal amount of NRG Yield Convertible Notes. Interest on the NRG Yield Convertible Notes is payable semi-annually in arrears on February 1 and August 1 of each year, commencing on August 1, 2014. The NRG Yield Convertible Notes mature on February 1, 2019, unless earlier repurchased or converted in accordance with their terms. Prior to the close of business on the business day immediately preceding August 1, 2018, the NRG Yield Convertible Notes will be convertible only upon the occurrence of certain events and during certain periods, and thereafter, at any time until the close of business on the second scheduled trading day immediately preceding the maturity date. The notes are accounted for in accordance with ASC 470-20. Under ASC 470-20, issuers of convertible debt instruments that may be settled in cash upon conversion, including partial cash settlement, are required to separately account for the liability (debt) and equity (conversion option) components. The equity component, the $23 million conversion option value, was recorded to NRG's noncontrolling interest for NRG Yield, Inc. with the offset to debt discount. The debt discount will be amortized to interest expense over the term of the notes.
NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility
NRG Yield LLC and Yield Operating entered into a senior secured revolving credit facility, which provides a revolving line of credit of $60 million. On April 25, 2014, NRG Yield LLC and Yield Operating amended the revolving credit facility to increase the available line of credit to $450 million and extend its maturity to April 2019. The revolving credit facility can be used for cash or for the issuance of letters of credit. There was no cash drawn or letters of credit issued under the revolving credit facility as of June 30, 2014.
Peakers
On February 21, 2014, NRG Peaker Finance Company LLC elected to redeem approximately $30 million of the outstanding bonds at a redemption price equal to the principal amount plus a redemption premium, accrued and unpaid interest, swap breakage, and other fees, totaling approximately $35 million in connection with the removal of Bayou Cove Peaking Power LLC from the peaker financing collateral package, which also involved limited commitments for certain repairs on other assets that were funded concurrently with the December 10, 2013 debt service payment. On March 3, 2014, Bayou Cove Peaking Power LLC sold Bayou Cove Unit 1, which the Company continues to manage and operate.

Variable_Interest_Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2014
Variable Interest Entities Disclosure [Abstract]	'
Variable Interest Entity	'
	Variable Interest Entities, or VIEs
	Entities that are not Consolidated
	NRG has interests in entities that are considered VIEs under ASC 810, Consolidation, but NRG is not considered the primary beneficiary.  NRG accounts for its interests in these entities under the equity method of accounting.
	GenConn Energy LLC — Through its consolidated subsidiary, Yield Operating, the Company owns a 50% interest in GenConn, which owns and operates two 190 MW peaking generation facilities in Connecticut at NRG's Devon and Middletown sites. NRG's maximum exposure to loss is limited to its equity investment, which was $116 million as of June 30, 2014.
	Sherbino I Wind Farm LLC — NRG owns a 50% interest in Sherbino, a joint venture with BP Wind Energy North America Inc. NRG's maximum exposure to loss is limited to its equity investment, which was $80 million as of June 30, 2014.
	Texas Coastal Ventures LLC — As of June 30, 2014, NRG owned a 50% interest in Texas Coastal Ventures, a joint venture with Hilcorp Energy I, L.P., through its subsidiary Petra Nova LLC. NRG's maximum exposure to loss is limited to its investment, which was $68 million as of June 30, 2014. As further described in Note 3, Business Acquisitions and Dispositions, on July 3, 2014, NRG, through its wholly owned subsidiary Petra Nova Holdings LLC, sold 50% of its interest in Petra Nova Parish Holdings LLC to JX Nippon Oil Exploration (EOR) Limited, reducing its ownership interest in Texas Coastal Ventures to 25%.
	Entities that are Consolidated
	Capistrano Wind LLC — Through the acquisition of EME, the Company has a controlling financial interest in Capistrano Wind Partners, whose Class B preferred equity interest are held by outside investors. Capistrano Wind Partners holds 100% ownership in five projects generating 411 MW of wind capacity. The five wind projects include Cedro Hill located in Texas, Mountain Wind Power I, located in Wyoming, Mountain Wind Power II located in Wyoming, Crofton Bluffs located in Nebraska, and Broken Bow I located in Nebraska.
	Under the terms of the Capistrano Wind Partners formation documents, preferred equity interests receive 100% of the cash available for distribution, up to a scheduled amount to target a certain return and thereafter cash distributions are shared. The Company retains indirect beneficial ownership of the wind projects and retains responsibilities for managing the operations of Capistrano Wind Partners. Accordingly, the Company consolidates these projects.
	The summarized financial information for Capistrano Wind Holdings consisted of the following:
	(In millions)	June 30, 2014
	Current assets	$	171
	Net property, plant and equipment	644
	Other long-term assets	6
	Total assets	821
	Current liabilities	29
	Long-term debt	188
	Other long-term liabilities	186
	Total liabilities	403
	Noncontrolling interests	$	388

Changes_in_Capital_Structure

Changes in Capital Structure	6 Months Ended
	Jun. 30, 2014
Changes in Capital Structure Disclosure [Abstract]	'
Changes in Capital Structure	'
	Changes in Capital Structure
	As of June 30, 2014 and December 31, 2013, the Company had 500,000,000 shares of common stock authorized. The following table reflects the changes in NRG's common stock issued and outstanding:
		Issued		Treasury			Outstanding
	Balance as of December 31, 2013	401,126,780		(77,347,528	)		323,779,252
	Shares issued under LTIPs	950,546		—			950,546
	Shares issued under ESPP	—		71,595			71,595
	Shares issued in connection with the EME acquisition	12,671,977		—			12,671,977
	Balance as of June 30, 2014	414,749,303		(77,275,933	)		337,473,370
	As discussed in Note 3, Business Acquisitions and Dispositions, on April 1, 2014, the Company issued 12,671,977 shares of NRG common stock in connection with the acquisition of EME.
	Employee Stock Purchase Plan
	On May 8, 2014, NRG stockholders approved an increase of 800,000 shares available for issuance under the NRG Energy, Inc. Amended and Restated Employee Stock Purchase Plan, or ESPP. Subsequent to this approval, 1,616,793 shares of treasury stock were available for issuance under the ESPP. In July 2014, 56,845 shares of NRG common stock were issued to employee accounts from treasury stock under the ESPP.
	NRG Common Stock Dividends
	The following table lists the dividends paid during the six months ended June 30, 2014:
		Second Quarter 2014			First Quarter 2014
	Dividends per Common Share	$	0.14		$	0.12
	On July 18, 2014, NRG declared a quarterly dividend on the Company's common stock of $0.14 per share, payable August 15, 2014, to stockholders of record as of August 1, 2014, representing $0.56 on an annualized basis. The Company's common stock dividends are subject to available capital, market conditions, and compliance with associated laws and regulations.

Earnings_Per_Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	(Loss)/Earnings Per Share
	Basic (loss)/earnings per common share is computed by dividing net (loss)/income less accumulated preferred stock dividends by the weighted average number of common shares outstanding. Shares issued and treasury shares repurchased during the year are weighted for the portion of the year that they were outstanding. Diluted (loss)/earnings per share is computed in a manner consistent with that of basic (loss)/earnings per share while giving effect to all potentially dilutive common shares that were outstanding during the period. The reconciliation of NRG's basic and diluted (loss)/earnings per share is shown in the following table:
		Three months ended June 30,							Six months ended June 30,
	(In millions, except per share data)	2014				2013			2014			2013
	Basic (loss)/earnings per share attributable to NRG Energy, Inc. common stockholders
	Net (loss)/income attributable to NRG Energy, Inc.	$	(97	)		$	124		$	(153	)	$	(208	)
	Dividends for preferred shares	3				3			5			5
	(Loss)/earnings available for common stockholders	$	(100	)		$	121		$	(158	)	$	(213	)
	Weighted average number of common shares outstanding	337				323			331			323
	(Loss)/earnings per weighted average common share — basic	$	(0.30	)		$	0.37		$	(0.48	)	$	(0.66	)
	Diluted (loss)/earnings per share attributable to NRG Energy, Inc. common stockholders
	Weighted average number of common shares outstanding	337				323			331			323
	Incremental shares attributable to the issuance of equity compensation (treasury stock method)	—				4			—			—
	Total dilutive shares	337				327			331			323
	(Loss)/earnings per weighted average common share — diluted	$	(0.30	)		$	0.37		$	(0.48	)	$	(0.66	)
	The following table summarizes NRG’s outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company’s diluted (loss)/earnings per share:
		Three months ended June 30,						Six months ended June 30,
	(In millions of shares)	2014			2013			2014		2013
	Equity compensation plans	8			2			8		11
	Embedded derivative of 3.625% redeemable perpetual preferred stock	16			16			16		16
	Total	24			18			24		27

Segment_Reporting

Segment Reporting	6 Months Ended
	Jun. 30, 2014
Segment Reporting Disclosure [Abstract]	'
Segment Reporting	'
	Segment Reporting
	Effective June 2014, the Company's segment structure and its allocation of corporate expenses were updated to reflect how management currently makes financial decisions and allocates resources. The Texas and South Central segments were combined to form the Gulf Coast segment. The Company has recast data from prior periods to reflect this change in reportable segments to conform to the current year presentation. The Company's businesses are primarily segregated based on the Retail Business, conventional power generation, renewable businesses, NRG Yield and corporate activities.  Within NRG's conventional power generation, there are distinct components with separate operating results and management structures for the following geographical regions: Gulf Coast, East and West. The Company's renewables segment includes solar and wind assets, excluding those in the NRG Yield segment. NRG Yield includes certain of the Company's contracted generation assets including four natural gas or dual-fired facilities, ten utility-scale solar and wind generation facilities, two portfolios of distributed solar facilities and thermal infrastructure assets. On June 30, 2014, NRG Yield acquired three projects from the Company: El Segundo Energy Center, formerly in the West segment, Kansas South and High Desert, both formerly in the renewables segment. As the transaction was accounted for as a transfer of entities under common control, all historical periods have been recast to reflect this change. The Company's corporate segment includes international business, electric vehicle services, energy services, residential solar and the carbon capture business. Intersegment sales are accounted for at market.
	(In millions)				Conventional Power Generation
	Three months ended June 30, 2014	Retail(a)			Gulf Coast(a)			East(a)			West(a)		Renewables(a)			NRG Yield(a)		Corporate(a)(b)			Elimination			Total
	Operating revenues	$	1,879		$	1,003		$	881		$	165	$	164		$	134	$	60		$	(665	)	$	3,621
	Depreciation and amortization	33			144			74			27		58			36		14			—			386
	Equity in earnings/(losses) of unconsolidated affiliates	—			1			1			10		(2		)	14		4			(14		)	14
	(Loss)/income before income taxes	(111		)	134			6			33		1			36		(290		)	(15		)	(206		)
	Net (loss)/income attributable to NRG Energy, Inc.	(112		)	134			6			33		(19		)	28		(166		)	(1		)	(97		)
	Total assets as of June 30, 2014	$	5,531		$	14,459		$	10,260		$	2,158	$	8,381		$	3,236	$	28,311		$	(34,707	)	$	37,629
	(a) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	2		$	698		$	(53	)	$	—	$	4		$	—	$	14
	(b) Includes loss on debt extinguishment of $40 million.
	(In millions)				Conventional Power Generation
	Three months ended June 30, 2013	Retail(c)			Gulf Coast(c)			East(c)			West(c)		Renewables(c)			NRG Yield(c)		Corporate(c)(d)			Elimination			Total
	Operating revenues	$	1,535		$	963		$	826		$	124	$	55		$	82	$	26		$	(682	)	$	2,929
	Depreciation and amortization	36			136			87			12		25			10		7			—			313
	Equity in earnings/(loss) of unconsolidated affiliates	—			1			—			1		(1		)	2		—			5			8
	(Loss)/income before income taxes	(82		)	180			133			36		(13		)	35		(219		)	(2		)	68
	Net (loss)/income attributable to NRG Energy, Inc.	$	(82	)	$	180		$	133		$	36	$	(22	)	$	35	$	(156	)	$	—		$	124
	(c) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	1		$	606		$	66		$	3	$	—		$	—	$	6
	(d) Includes loss on debt extinguishment of $21 million.
	(In millions)				Conventional Power Generation
	Six months ended June 30, 2014	Retail(e)			Gulf Coast(e)			East(e)			West(e)		Renewables(e)			NRG Yield(e)		Corporate(e)(f)			Elimination			Total
	Operating revenues	$	3,405		$	1,477		$	2,281		$	275	$	214		$	274	$	98		$	(917	)	$	7,107
	Depreciation and amortization	66			287			140			39		106			60		23			—			721
	Equity in earnings/(losses) of unconsolidated affiliates	—			1			—			14		(6		)	15		4			(7		)	21
	Income/(loss) before income taxes	180			(203		)	225			41		(64		)	65		(526		)	(22		)	(304		)
	Net income/(loss) attributable to NRG Energy, Inc.	$	179		$	(203	)	$	225		$	41	$	(67	)	$	50	$	(372	)	$	(6	)	$	(153	)
	(e) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	4		$	839		$	30		$	—	$	4		$	—	$	40
	(f) Includes loss on debt extinguishment of $81 million
	(In millions)				Conventional Power Generation
	Six months ended June 30, 2013	Retail(g)			Gulf Coast(g)			East(g)			West(g)		Renewables(g)			NRG Yield(g)		Corporate(g)(h)			Elimination			Total
	Operating revenues	$	2,766		$	1,243		$	1,421		$	213	$	89		$	135	$	57		$	(914	)	$	5,010
	Depreciation and amortization	68			273			173			25		48			20		13			—			620
	Equity in earnings of unconsolidated affiliates	—			2			—			2		1			6		—			—			11
	Income/(loss) before income taxes	287			(251		)	(25		)	32		(28		)	46		(470		)	(6		)	(415		)
	Net income/(loss) attributable to NRG Energy, Inc.	$	287		$	(251	)	$	(25	)	$	32	$	(38	)	$	46	$	(255	)	$	(4	)	$	(208	)
	(g) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	2		$	837		$	58		$	3	$	—		$	—	$	14
	(h) Includes loss on debt extinguishment of $49 million

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	Effective Tax Rate
	The income tax provision consisted of the following:
		Three months ended June 30,						Six months ended June 30,
	(In millions except otherwise noted)	2014			2013			2014			2013
	(Loss)/income before income taxes	$	(206	)	$	68		$	(304	)	$	(415	)
	Income tax benefit	(126		)	(63		)	(157		)	(215		)
	Effective tax rate	61.2		%	(92.6		)%	51.6		%	51.8		%
	For the three and six months ended June 30, 2014, NRG's overall effective tax rate was different than the statutory rate of 35% primarily due to the impact of production tax credits generated from our wind assets and the recognition of uncertain tax benefits.
	For the three and six months ended June 30, 2013, NRG's overall effective tax rate was different than the statutory rate of 35% primarily due to the recognition of ITCs from the Company's Agua Caliente solar project in Arizona and the impact of non-taxable equity earnings.
	Uncertain Tax Benefits
	As of June 30, 2014, NRG has recorded a non-current tax liability of $68 million for uncertain tax benefits from positions taken on various state income tax returns, including accrued interest. NRG has accrued interest related to these uncertain tax benefits of $1 million for the six months ended June 30, 2014, and has accrued $15 million of interest and penalties since adoption. The Company recognizes interest and penalties related to uncertain tax benefits in income tax expense.
	NRG is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state and foreign jurisdictions including operations located in Australia. The Company is not subject to U.S. federal income tax examinations for years prior to 2010. With few exceptions, state and local income tax examinations are no longer open for years before 2004. The Company's primary foreign operations are also no longer subject to examination by local jurisdictions for years prior to 2010.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Commitments
	This footnote should be read in conjunction with the complete description under Note 22, Commitments and Contingencies, to the Company's 2013 Form 10-K.
	First Lien Structure
	NRG has granted first liens to certain counterparties on a substantial portion of the Company's assets, excluding assets acquired in the GenOn acquisition, assets held by NRG Yield, Inc. and NRG's assets that have project-level financing to reduce the amount of cash collateral and letters of credit that it would otherwise be required to post from time to time to support its obligations under out-of-the-money hedge agreements for forward sales of power or MWh equivalents. The Company's lien counterparties may have a claim on NRG's assets to the extent market prices exceed the hedged price. As of June 30, 2014, hedges under the first lien were out-of-the-money for NRG on a counterparty aggregate basis.
	Contingencies
	The Company's material legal proceedings are described below. The Company believes that it has valid defenses to these legal proceedings and intends to defend them vigorously. NRG records reserves for estimated losses from contingencies when information available indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. In addition, legal costs are expensed as incurred. Management has assessed each of the following matters based on current information and made a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. Unless specified below, the Company is unable to predict the outcome of these legal proceedings or reasonably estimate the scope or amount of any associated costs and potential liabilities. As additional information becomes available, management adjusts its assessment and estimates of such contingencies accordingly. Because litigation is subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of the Company's liabilities and contingencies could be at amounts that are different from its currently recorded reserves and that such difference could be material.
	In addition to the legal proceedings noted below, NRG and its subsidiaries are party to other litigation or legal proceedings arising in the ordinary course of business. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect NRG's consolidated financial position, results of operations, or cash flows.
	Midwest Generation, LLC Asbestos Liabilities
	The Company, through its subsidiary, Midwest Generation, LLC, may be subject to potential asbestos liabilities as a result of its acquisition of EME. The Company is currently analyzing the scope of potential liability as it may relate to Midwest Generation, LLC.
	NRG Energy Center San Francisco LLC
	In 2013, NRG Energy Center San Francisco LLC received a Notice of Violation from the San Francisco Department of Public Health alleging improper monitoring of three underground storage tanks. The tanks have not leaked. This matter was settled on July 21, 2014 for $123,270.
	Louisiana Generating, LLC
	Big Cajun II Alleged Opacity Violations — On September 7, 2012, LaGen received a Consolidated Compliance Order & Notice of Potential Penalty, or CCO&NPP, from the LDEQ.  The CCO&NPP alleges there were opacity exceedance events from the Big Cajun II Power Plant on certain dates during the years 2007-2012. In February 2014, LaGen and LDEQ settled this matter for approximately $47,000.
	Actions Pursued by MC Asset Recovery
	With Mirant Corporation's emergence from bankruptcy protection in 2006, certain actions filed by GenOn Energy Holdings and some of its subsidiaries against third parties were transferred to MC Asset Recovery, a wholly owned subsidiary of GenOn Energy Holdings. MC Asset Recovery is governed by a manager who is independent of NRG and GenOn.  MC Asset Recovery is a disregarded entity for income tax purposes. Under the remaining action transferred to MC Asset Recovery, MC Asset Recovery seeks to recover damages from Commerzbank AG and various other banks, or the Commerzbank Defendants, for alleged fraudulent transfers that occurred prior to Mirant's bankruptcy proceedings.  In December 2010, the U.S. District Court for the Northern District of Texas dismissed MC Asset Recovery's complaint against the Commerzbank Defendants.  In January 2011, MC Asset Recovery appealed the District Court's dismissal of its complaint against the Commerzbank Defendants to the U.S. Court of Appeals for the Fifth Circuit.  In March 2012, the Court of Appeals reversed the District Court's dismissal and reinstated MC Asset Recovery's amended complaint against the Commerzbank Defendants.  If MC Asset Recovery succeeds in obtaining any recoveries from the Commerzbank Defendants, the Commerzbank Defendants have asserted that they will seek to file claims in Mirant's bankruptcy proceedings for the amount of those recoveries.  GenOn Energy Holdings would vigorously contest the allowance of any such claims. If the Commerzbank Defendants were to receive an allowed claim as a result of a recovery by MC Asset Recovery on its claims against them, GenOn Energy Holdings would retain from the net amount recovered by MC Asset Recovery an amount equal to the dollar amount of the resulting allowed claim.
	Pending Natural Gas Litigation
	GenOn is party to several lawsuits, certain of which are class action lawsuits, in state and federal courts in Kansas, Missouri, Nevada and Wisconsin. These lawsuits were filed in the aftermath of the California energy crisis in 2000 and 2001 and the resulting FERC investigations and relate to alleged conduct to increase natural gas prices in violation of antitrust and similar laws. The lawsuits seek treble or punitive damages, restitution and/or expenses. The lawsuits also name as parties a number of energy companies unaffiliated with NRG. In July 2011, the U.S. District Court for the District of Nevada, which is handling four of the five cases, granted the defendants' motion for summary judgment and dismissed all claims against GenOn in those cases. The plaintiffs appealed to the U.S. Court of Appeals for the Ninth Circuit. The Court of Appeals reversed the decision of the District Court. On August 26, 2013, GenOn along with the other defendants in the lawsuit filed a petition for a writ of certiorari to the U.S. Supreme Court challenging the Court of Appeal’s decision. On July 1, 2014, the U.S. Supreme Court granted the petition for a writ of certiorari.
	In September 2012, the State of Nevada Supreme Court, which is handling the remaining case, affirmed dismissal by the Eighth Judicial District Court for Clark County, Nevada of all plaintiffs' claims against GenOn. In February 2013, the plaintiffs in the Nevada case filed a petition for a writ of certiorari to the U.S. Supreme Court. In June 2013, the U.S. Supreme Court denied the petition for a writ of certiorari, thereby ending one of the five lawsuits. GenOn has agreed to indemnify CenterPoint against certain losses relating to these lawsuits.
	Cheswick Class Action Complaint
	In April 2012, a putative class action lawsuit was filed against GenOn in the Court of Common Pleas of Allegheny County, Pennsylvania alleging that emissions from the Cheswick generating facility have damaged the property of neighboring residents. The Company disputes these allegations. Plaintiffs have brought nuisance, negligence, trespass and strict liability claims seeking both damages and injunctive relief. Plaintiffs seek to certify a class that consists of people who own property or live within one mile of the Company's plant. In July 2012, the Company removed the lawsuit to the U.S. District Court for the Western District of Pennsylvania. In October 2012, the District Court granted the Company's motion to dismiss, which plaintiffs appealed to the U.S. Court of Appeals for the Third Circuit. On August 20, 2013, the Court of Appeals reversed the decision of the District Court. On September 3, 2013, the Company filed a petition for rehearing with the Court of Appeals which was subsequently denied. In February 2014, the Company filed a petition for a writ of certiorari to the U.S. Supreme Court seeking review and reversal of the Court of Appeals decision. On June 2, 2014, the U.S. Supreme Court denied the petition for a writ of certiorari. The case is proceeding in the U.S. District Court for the Western District of Pennsylvania.
	Cheswick Monarch Mine NOV
	In 2008, the PADEP issued an NOV related to the Monarch mine located near the Cheswick generating facility. It has not been mined for many years. The Company uses the Monarch mine for disposal of low-volume wastewater from the Cheswick generating facility and for disposal of leachate collected from ash disposal facilities. The NOV addresses the alleged requirement to maintain a minimum pumping volume from the mine. The PADEP indicated it will seek a civil penalty of approximately $200,000. The Company contests the allegations in the NOV and has not agreed to such penalty. The Company is currently planning to incur capital expenditures in connection with wastewater from Cheswick and leachate from ash disposal facilities.
	Energy Plus Holdings
	In May 2014, Energy Plus Holdings executed a settlement agreement with the Connecticut Office of Attorney General and the Connecticut Office of Consumer Counsel related to its sales, marketing and business practices in Connecticut. The settlement was in accordance with the Company's established reserve for this matter.  Energy Plus Holdings continues to cooperate and discuss a resolution of issues with respect to its sales, marketing and business practices in New York with the New York Office of Attorney General.
	Maryland Department of the Environment v. GenOn Chalk Point and GenOn Mid-Atlantic
	On January 25, 2013, Food & Water Watch, the Patuxent Riverkeeper and the Potomac Riverkeeper (together, the Citizens Group) sent NRG a letter alleging that the Chalk Point, Dickerson and Morgantown generating facilities were violating the terms of the three National Pollution Discharge Elimination System permits by discharging nitrogen and phosphorous in excess of the limits in each permit. On March 21, 2013, the MDE sent the Company a similar letter with respect to the Chalk Point and Dickerson facilities, threatening to sue within 60 days if the Company did not bring itself into compliance. On June 11, 2013, the Maryland Attorney General on behalf of the MDE filed a complaint in the U.S. District Court for the District of Maryland alleging violations of the Clean Water Act and Maryland environmental laws related to water. The lawsuit is ongoing and seeks injunctive relief and civil penalties in excess of $100,000.

Regulatory_Matters

Regulatory Matters	6 Months Ended
	Jun. 30, 2014
Regulatory Matters Disclosure [Abstract]	'
Regulatory Matters	'
	Regulatory Matters
	This footnote should be read in conjunction with the complete description under Note 23, Regulatory Matters, to the Company's 2013 Form 10-K.
	NRG operates in a highly regulated industry and is subject to regulation by various federal and state agencies. As such, NRG is affected by regulatory developments at both the federal and state levels and in the regions in which NRG operates. In addition, NRG is subject to the market rules, procedures, and protocols of the various ISO and RTO markets in which NRG participates. These power markets are subject to ongoing legislative and regulatory changes that may impact NRG's wholesale and retail businesses.
	In addition to the regulatory proceedings noted below, NRG and its subsidiaries are a party to other regulatory proceedings arising in the ordinary course of business or have other regulatory exposure. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect NRG's consolidated financial position, results of operations, or cash flows.
	National
	Court Rejects FERC’s Jurisdiction Over Demand Response — On May 23, 2014, the U.S. Court of Appeals for the District of Columbia Circuit vacated FERC’s rules (known as Order No. 745) that allow demand response resources to participate in the FERC-jurisdictional energy markets. The Court of Appeals held that the Federal Power Act does not authorize FERC to exercise jurisdiction over demand response and that instead demand response is part of the retail market over which the states have jurisdiction. The specific order being challenged related solely to energy market participation, but this ruling also calls into question whether demand response will be permitted to participate in the capacity markets in the future. FERC has asked the U.S. Court of Appeals for the District of Columbia Circuit to rehear en banc the decision. The eventual outcome of this proceeding could result in refunds of payments made for non-jurisdictional services and resettlement of wholesale markets but it is not possible to estimate the impact on the Company at this time.
	West Region
	California Station Power — On December 18, 2012, in Calpine Corporation v. FERC, the U.S. Court of Appeals for the District of Columbia Circuit upheld a decision by FERC disclaiming jurisdiction over how the states impose retail station power charges. The CPUC may now establish retail charges for future station power consumption. Due to reservation-of-rights language in the California utilities' state-jurisdictional station power tariffs, the ruling of the Court of Appeals may require California generators to pay state-imposed retail charges back to the date of enrollment by the facilities in the CAISO's station period program (February 1, 2009, for the Company's Encina and El Segundo facilities; March 1, 2009, for the Company's Long Beach facility).
	On November 18, 2011, Southern California Edison Company, or SCE, filed with the CPUC, seeking authorization to begin charging generators station power charges, and to assess such charges retroactively, which the Company and other generators have challenged. On July 14, 2014, the CPUC issued a draft resolution describing the method to be used by SCE and PG&E to determine station power charges. The draft resolution establishes a 15 minute netting period, to take effect August 30, 2010, which means that there would be no refund liability associated with station power consumption prior to August 30, 2010. The draft resolution remains under consideration by the CPUC and is scheduled for Commission action on August 14, 2014. If approved, the Company would have 30 days to appeal the ruling before it would be considered final.
	Gulf Coast Region
	South Texas Project — On March 31, 2014, STP submitted the response to a request for information from the NRC regarding the re-evaluation of the seismic hazard at the site, conducted in response to recommendation 2.1 of the Near-Term Task Force that was convened in response to the accident at Fukushima. On March 12, 2012, after the initial industry-wide submittal was reviewed by the NRC, the agency questioned the varying standards applied to risk assessment for seismic hazards used for initial licensing at some stations. As a result, all stations were directed to re-evaluate the risk against present-day requirements and the current design basis. The seismic evaluation of the STP site, recently conducted when preparing the application for a combined construction and operating license for the STP Units 3 & 4 development project, provided some assurance of the adequacy of the walk-downs and analyses to be conducted. The station followed the guidance in the “Seismic Evaluation Guidance: Screening, Prioritization, and Implementation Details (SPID) for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic” report published by the Electric Power Research Institute. This re-evaluation confirmed that the updated ground motion response spectrum does not exceed the bounds of the operating license and as a result, no further evaluations need to be performed.

Environmental_Matters

Environmental Matters	6 Months Ended
	Jun. 30, 2014
Environmental Matters Disclosure [Abstract]	'
Environmental Matters	'
	Environmental Matters
	This footnote should be read in conjunction with the complete description under Note 24, Environmental Matters, to the Company's 2013 Form 10-K.
	NRG is subject to a wide range of environmental laws in the development, ownership, construction and operation of projects in the United States and certain international regions. These laws generally require that governmental permits and approvals be obtained before construction and during operation of power plants. Environmental laws have become increasingly stringent and NRG expects this trend to continue. The electric generation industry is likely to face new requirements to address various emissions, including greenhouse gases, as well as combustion byproducts, water discharge and use, and threatened and endangered species. In general, future laws are expected to require the addition of emissions controls or other environmental controls or to impose certain restrictions on the operations of the Company's facilities, which could have a material effect on the Company's operations.
	The EPA released CSAPR in 2011, which was scheduled to replace CAIR in January 2012. In December 2011, the U.S. Court of Appeals for the District of Columbia Circuit stayed the implementation of CSAPR and then issued an opinion in August 2012 vacating CSAPR and keeping CAIR in place until the EPA can replace it. On April 29, 2014, the U.S. Supreme Court reversed and remanded the D.C. Circuit's opinion. The Company expects further proceedings in the Court of Appeals over the next few months. While NRG is unable to predict the final outcome of the ongoing litigation, the Company believes its investment in pollution controls and cleaner technologies coupled with planned plant retirements should leave the fleet well positioned for compliance.
	In January 2014, the EPA re-proposed the NSPS for CO2 emissions from new fossil-fuel-fired electric generating units that had been previously proposed in April 2012. The re-proposed standards are 1,000 pounds of CO2 per MWh for large gas units and 1,100 pounds of CO2 per MWh for coal units and small gas units. Proposed standards are in effect until a final rule is published or another rule is re-proposed. On June 18, 2014, the EPA proposed a rule that would require states to develop CO2 emission standards that would apply to existing fossil-fueled generating facilities. Specifically, the EPA proposed state-specific rate-based standards for CO2 emissions, as well as guidelines for states to follow in developing plans to achieve the state-specific standards. The EPA anticipates finalizing this rule in June 2015.
	Water
	In May 2014, the EPA released a prepublication version of the final regulation regarding once through cooling from existing facilities to address impingement and entrainment concerns. NRG anticipates that more stringent requirements will be incorporated into some of its water discharge permits over the next several years.
	East Region
	The MDE has announced that it intends to promulgate more stringent regulations regarding SO2 and NOx emissions, which could negatively affect certain of the Company's coal facilities located in Maryland.
	Environmental Capital Expenditures
	Based on current rules, technology and preliminary plans based on some proposed rules, NRG estimates that environmental capital expenditures from 2014 through 2018 required to comply with environmental laws will be approximately $906 million which includes $123 million for GenOn and $567 million (of which $22 million is attributable to interest during construction) for plants acquired in the EME acquisition.
	In connection with the acquisition of EME, as further described in Note 3, Business Acquisitions and Dispositions, NRG has committed to fund up to $350 million in capital expenditures for plant modifications at Powerton and Joliet to comply with environmental regulations.

Condensed_Consolidating_Financ

Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2014
Condensed Consolidating Financial Information Disclosure [Abstract]	'
Condensed Consolidating Financial Information	'
	Condensed Consolidating Financial Information
	As of June 30, 2014, the Company had outstanding $6.6 billion of Senior Notes due from 2018 - 2024, as shown in Note 7, Debt and Capital Leases. These Senior Notes are guaranteed by certain of NRG's current and future 100% owned domestic subsidiaries, or guarantor subsidiaries. These guarantees are both joint and several. The non-guarantor subsidiaries include all of NRG's foreign subsidiaries and certain domestic subsidiaries, including GenOn and its subsidiaries, NRG Yield, Inc. and its subsidiaries and other subsidiaries of NRG that are subject to project financing.
	Unless otherwise noted below, each of the following guarantor subsidiaries fully and unconditionally guaranteed the Senior Notes as of June 30, 2014:
	Ace Energy, Inc.	Middletown Power LLC	NRG Oswego Harbor Power Operations Inc.
	Allied Warranty LLC	Montville Power LLC	NRG PacGen Inc.
	Arthur Kill Power LLC	NEO Corporation	NRG Portable Power LLC
	Astoria Gas Turbine Power LLC	NEO Freehold-Gen LLC	NRG Power Marketing LLC
	Bayou Cove Peaking Power, LLC	NEO Power Services Inc.	NRG Reliability Solutions LLC
	BidURenergy, Inc.	New Genco GP, LLC	NRG Renter's Protection LLC
	Cabrillo Power I LLC	Norwalk Power LLC	NRG Retail LLC
	Cabrillo Power II LLC	NRG Affiliate Services Inc.	NRG Retail Northeast LLC
	Carbon Management Solutions LLC	NRG Artesian Energy LLC	NRG Rockford Acquisition LLC
	Cirro Group, Inc.	NRG Arthur Kill Operations Inc.	NRG Saguaro Operations Inc.
	Cirro Energy Services, Inc.	NRG Astoria Gas Turbine Operations Inc.	NRG Security LLC
	Clean Edge Energy LLC	NRG Bayou Cove LLC	NRG Services Corporation
	Conemaugh Power LLC	NRG Business Solutions LLC	NRG SimplySmart Solutions LLC
	Connecticut Jet Power LLC	NRG Cabrillo Power Operations Inc.	NRG South Central Affiliate Services Inc.
	Cottonwood Development LLC	NRG California Peaker Operations LLC	NRG South Central Generating LLC
	Cottonwood Energy Company LP	NRG Cedar Bayou Development Company, LLC	NRG South Central Operations Inc.
	Cottonwood Generating Partners I LLC	NRG Connecticut Affiliate Services Inc.	NRG South Texas LP
	Cottonwood Generating Partners II LLC	NRG Construction LLC	NRG Texas C&I Supply LLC
	Cottonwood Generating Partners III LLC	NRG Curtailment Solutions LLC	NRG Texas Gregory LLC
	Cottonwood Technology Partners LP	NRG Development Company Inc.	NRG Texas Holding Inc.
	Devon Power LLC	NRG Devon Operations Inc.	NRG Texas LLC
	Dunkirk Power LLC	NRG Dispatch Services LLC	NRG Texas Power LLC
	Eastern Sierra Energy Company LLC	NRG Dunkirk Operations Inc.	NRG Warranty Services LLC
	El Segundo Power, LLC	NRG El Segundo Operations Inc.	NRG West Coast LLC
	El Segundo Power II LLC	NRG Energy Labor Services LLC	NRG Western Affiliate Services Inc.
	Elbow Creek Wind Project LLC	NRG Energy Services Group LLC	O'Brien Cogeneration, Inc. II
	Energy Alternatives Wholesale, LLC	NRG Energy Services International Inc.	ONSITE Energy, Inc.
	Energy Curtailment Specialists, Inc.	NRG Energy Services LLC	Oswego Harbor Power LLC
	Energy Plus Holdings LLC	NRG Generation Holdings, Inc.	RE Retail Receivables, LLC
	Energy Plus Natural Gas LLC	NRG Home & Business Solutions LLC	Reliant Energy Northeast LLC
	Energy Protection Insurance Company	NRG Home Solutions LLC	Reliant Energy Power Supply, LLC
	Everything Energy LLC	NRG Home Solutions Product LLC	Reliant Energy Retail Holdings, LLC
	GCP Funding Company, LLC	NRG Homer City Services LLC	Reliant Energy Retail Services, LLC
	Green Mountain Energy Company	NRG Huntley Operations Inc.	RERH Holdings LLC
	Green Mountain Energy Company	NRG Identity Protect LLC	Saguaro Power LLC
	(NY Res) LLC	NRG Ilion Limited Partnership	Somerset Operations Inc.
	Gregory Partners, LLC	NRG Ilion LP LLC	Somerset Power LLC
	Gregory Power Partners LLC	NRG International LLC	Texas Genco Financing Corp.
	Huntley Power LLC	NRG Maintenance Services LLC	Texas Genco GP, LLC
	Independence Energy Alliance LLC	NRG Mextrans Inc.	Texas Genco Holdings, Inc.
	Independence Energy Group LLC	NRG MidAtlantic Affiliate Services Inc.	Texas Genco LP, LLC
	Independence Energy Natural Gas LLC	NRG Middletown Operations Inc.	Texas Genco Operating Services, LLC
	Indian River Operations Inc.	NRG Montville Operations Inc.	Texas Genco Services, LP
	Indian River Power LLC	NRG New Jersey Energy Sales LLC	US Retailers LLC
	Keystone Power LLC	NRG New Roads Holdings LLC	Vienna Operations Inc.
	Langford Wind Power, LLC	NRG North Central Operations Inc.	Vienna Power LLC
	Lone Star A/C & Appliance Repairs, LLC	NRG Northeast Affiliate Services Inc.	WCP (Generation) Holdings LLC
	Louisiana Generating LLC	NRG Norwalk Harbor Operations Inc.	West Coast Power LLC
	Meriden Gas Turbines LLC	NRG Operating Services, Inc.
	NRG conducts much of its business through and derives much of its income from its subsidiaries. Therefore, the Company's ability to make required payments with respect to its indebtedness and other obligations depends on the financial results and condition of its subsidiaries and NRG's ability to receive funds from its subsidiaries. There are no restrictions on the ability of any of the guarantor subsidiaries to transfer funds to NRG. However, there may be restrictions for certain non-guarantor subsidiaries.
	The following condensed consolidating financial information presents the financial information of NRG Energy, Inc., the guarantor subsidiaries and the non-guarantor subsidiaries in accordance with Rule 3-10 under the SEC Regulation S-X. The financial information may not necessarily be indicative of results of operations or financial position had the guarantor subsidiaries or non-guarantor subsidiaries operated as independent entities.
	In this presentation, NRG Energy, Inc. consists of parent company operations. Guarantor subsidiaries and non-guarantor subsidiaries of NRG are reported on an equity basis. For companies acquired, the fair values of the assets and liabilities acquired have been presented on a push-down accounting basis.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Three Months Ended June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Operating Revenues
Total operating revenues	$	2,514		$	1,129		$	—		$	(22	)	$	3,621
Operating Costs and Expenses
Cost of operations	2,048			762			11			(4		)	2,817
Depreciation and amortization	211			170			5			—			386
Selling, general and administrative	106			82			80			—			268
Acquisition-related transaction and integration costs	—			7			33			—			40
Development activity expenses	—			7			14			—			21
Total operating costs and expenses	2,365			1,028			143			(4		)	3,532
Operating Income/(Loss)	149			101			(143		)	(18		)	89
Other Income/(Expense)
Equity in earnings of consolidated subsidiaries	52			—			65			(117		)	—
Equity in earnings of unconsolidated affiliates	6			17			—			(9		)	14
Other income/(loss), net	3			4			(2		)	—			5
Loss on debt extinguishment	—			—			(40		)	—			(40		)
Interest expense	(5		)	(120		)	(149		)	—			(274		)
Total other income/(expense)	56			(99		)	(126		)	(126		)	(295		)
Income/(Loss) Before Income Taxes	205			2			(269		)	(144		)	(206		)
Income tax expense/(benefit)	47			4			(177		)	—			(126		)
Net Income/(Loss)	158			(2		)	(92		)	(144		)	(80		)
Less: Net income attributable to noncontrolling interest	—			39			5			(27		)	17
Net Income/(Loss) attributable to	$	158		$	(41	)	$	(97	)	$	(117	)	$	(97	)
NRG Energy, Inc.
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Six Months Ended June 30, 2014
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Operating Revenues
Total operating revenues	$	4,793		$	2,380		$	—		$	(66	)	$	7,107
Operating Costs and Expenses
Cost of operations	3,841			1,736			7			(34		)	5,550
Depreciation and amortization	409			304			8			—			721
Selling, general and administrative	211			139			144			—			494
Acquisition-related transaction and integration costs	—			8			44			—			52
Development activity expenses	—			17			23			—			40
Total operating costs and expenses	4,461			2,204			226			(34		)	6,857
Gain on sale of assets	—			19			—			—			19
Operating Income/(Loss)	332			195			(226		)	(32		)	269
Other Income/(Expense)
Equity in earnings/(loss) of consolidated subsidiaries	101			(6		)	180			(275		)	—
Equity in earnings of unconsolidated affiliates	10			18			—			(7		)	21
Other income, net	4			8			5			(1		)	16
Loss on debt extinguishment	—			(9		)	(72		)	—			(81		)
Interest expense	(11		)	(227		)	(292		)	1			(529		)
Total other income/(expense)	104			(216		)	(179		)	(282		)	(573		)
Income/(Loss) Before Income Taxes	436			(21		)	(405		)	(314		)	(304		)
Income tax expense/(benefit)	110			(6		)	(261		)	—			(157		)
Net Income/(Loss)	326			(15		)	(144		)	(314		)	(147		)
Less: Net income attributable to noncontrolling interest	—			36			9			(39		)	6
Net Income/(Loss) attributable to	$	326		$	(51	)	$	(153	)	$	(275	)	$	(153	)
NRG Energy, Inc.
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME/(LOSS)
For the Three Months Ended June 30, 2014
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Net Income/(Loss)	$	158		$	(2	)	$	(92	)	$	(144	)	$	(80	)
Other comprehensive income, net of tax
Unrealized gain/(loss) on derivatives, net	2			(20		)	(8		)	7			(19		)
Foreign currency translation adjustments, net	—			(1		)	(2		)	—			(3		)
Available-for-sale securities, net	—			5			4			(2		)	7
Defined benefit plan, net	(2		)	(13		)	25			—			10
Other comprehensive income/(loss)	—			(29		)	19			5			(5		)
Comprehensive income/(loss)	158			(31		)	(73		)	(139		)	(85		)
Less: Comprehensive income attributable to noncontrolling interest	—			32			5			(25		)	12
Comprehensive income/(loss) attributable to NRG Energy, Inc.	158			(63		)	(78		)	(114		)	(97		)
Dividends for preferred shares	—			—			3			—			3
Comprehensive income/(loss) available for common stockholders	$	158		$	(63	)	$	(81	)	$	(114	)	$	(100	)
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME/(LOSS)
For the Six Months Ended June 30, 2014
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Net Income/(Loss)	$	326		$	(15	)	$	(144	)	$	(314	)	$	(147	)
Other comprehensive income, net of tax
Unrealized gain/(loss) on derivatives, net	8			(26		)	(3		)	(7		)	(28		)
Foreign currency translation adjustments, net	—			5			(2		)	—			3
Available-for-sale securities, net	—			5			8			—			13
Defined benefit plan, net	—			(13		)	25			—			12
Other comprehensive income/(loss)	8			(29		)	28			(7		)	—
Comprehensive income/(loss)	334			(44		)	(116		)	(321		)	(147		)
Less: Comprehensive income/(loss) attributable to noncontrolling interest	—			27			9			(39		)	(3		)
Comprehensive income/(loss) attributable to NRG Energy, Inc.	334			(71		)	(125		)	(282		)	(144		)
Dividends for preferred shares	—			—			5			—			5
Comprehensive income/(loss) available for common stockholders	$	334		$	(71	)	$	(130	)	$	(282	)	$	(149	)
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
June 30, 2014
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	25		$	1,121		$	335		$	—		$	1,481
Funds deposited by counterparties	5			4			—			—			9
Restricted cash	9			276			1			—			286
Accounts receivable, net	1,205			277			—			—			1,482
Inventory	419			577			—			—			996
Derivative instruments	989			852			—			(140		)	1,701
Deferred income taxes	—			41			38			—			79
Cash collateral paid in support of energy risk management activities	282			290			—			—			572
Accounts receivable - affiliate	5,661			821			(4,748		)	(1,724		)	10
Renewable energy grant receivable	—			614			—			—			614
Prepayments and other current assets	128			367			32			—			527
Total current assets	8,723			5,240			(4,342		)	(1,864		)	7,757
Net property, plant and equipment	8,884			12,563			153			(24		)	21,576
Other Assets
Investment in subsidiaries	573			(932		)	22,474			(22,115		)	—
Equity investments in affiliates	(20		)	1,014			—			(129		)	865
Notes receivable, less current portion	—			73			108			(96		)	85
Goodwill	2,064			52						—			2,116
Intangible assets, net	958			545			(47		)	(22		)	1,434
Nuclear decommissioning trust fund	576			—			—			—			576
Deferred income tax	8			586			906			—			1,500
Derivative instruments	172			269			—			(28		)	413
Other non-current assets	96			637			574						1,307
Total other assets	4,427			2,244			24,015			(22,390		)	8,296
Total Assets	$	22,034		$	20,047		$	19,826		$	(24,278	)	$	37,629
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Current portion of long-term debt and capital leases	$	1		$	813		$	19		$	—		$	833
Accounts payable	748			325			30			—			1,103
Accounts payable — affiliate	1,054			365			305			(1,724		)	—
Derivative instruments	1,029			847			—			(140		)	1,736
Cash collateral received in support of energy risk management activities	5			4			—			—			9
Accrued expenses and other current liabilities	283			491			291						1,065
Total current liabilities	3,120			2,845			645			(1,864		)	4,746
Other Liabilities
Long-term debt and capital leases	316			9,272			8,673			(96		)	18,165
Nuclear decommissioning reserve	302			—			—			—			302
Nuclear decommissioning trust liability	336			—			—			—			336
Deferred income taxes	1,142			(1,003		)	(68		)	—			71
Derivative instruments	189			194			—			(29		)	354
Out-of-market contracts	119			1,056			—			—			1,175
Other non-current liabilities	424			583			247						1,254
Total non-current liabilities	2,828			10,102			8,852			(125		)	21,657
Total liabilities	5,948			12,947			9,497			(1,989		)	26,403
3.625% convertible perpetual preferred stock	—			—			249			—			249
Stockholders’ Equity	16,086			7,100			10,080			(22,289		)	10,977
Total Liabilities and Stockholders’ Equity	$	22,034		$	20,047		$	19,826		$	(24,278	)	$	37,629
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2014
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Cash Flows from Operating Activities
Net Cash Provided/(Used) by Operating Activities	$	798		$	641		$	(2,429	)	$	1,360		$	370
Cash Flows from Investing Activities
(Payments for)/proceeds from intercompany loans to subsidiaries	(808		)	(552		)	1,360			—			—
Acquisition of businesses, net of cash acquired	—			(25		)	(1,792		)	—			(1,817		)
Capital expenditures	(9		)	(134		)	(364		)	—			(507		)
(Increase)/decrease in restricted cash, net	(2		)	(5		)	1			—			(6		)
Decrease/(increase) in restricted cash — U.S. DOE projects	—			24			(3		)	—			21
Decrease in notes receivable	—			2			—			—			2
Investments in nuclear decommissioning trust fund securities	(340		)	—			—			—			(340		)
Proceeds from sales of nuclear decommissioning trust fund securities	334			—			—			—			334
Proceeds from renewable energy grants	—			429			—			—			429
Proceeds from sale of assets, net of cash disposed of	—			—			77			—			77
Cash proceeds to fund cash grant bridge loan payment	—			57			—			—			57
Other	(4		)	1			—			—			(3		)
Net Cash Used by Investing Activities	(829		)	(203		)	(721		)	—			(1,753		)
Cash Flows from Financing Activities
Proceeds from/(payments for) intercompany loans	—			—			1,360			(1,360		)	—
Payment of dividends to common and preferred stockholders	—			—			(91		)	—			(91		)
Net payments for settlement of acquired derivatives that include financing elements	—			(167		)	—			—			(167		)
Contributions from noncontrolling interest in subsidiaries	—			10			—			—			10
Proceeds from issuance of long-term debt	—			551			3,335			—			3,886
Proceeds from issuance of common stock	—			—			8			—			8
Payment of debt issuance and hedging costs	—			(15		)	(28		)	—			(43		)
Payments for short and long-term debt	—			(542		)	(2,427		)	—			(2,969		)
Net Cash (Used)/Provided by Financing Activities	—			(163		)	2,157			(1,360		)	634
Effect of exchange rate changes on cash and cash equivalents	—			(24		)	—			—			(24		)
Net (Decrease)/Increase in Cash and Cash Equivalents	(31		)	251			(993		)	—			(773		)
Cash and Cash Equivalents at Beginning of Period	56			870			1,328			—			2,254
Cash and Cash Equivalents at End of Period	$	25		$	1,121		$	335		$	—		$	1,481
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Operating Revenues
Total operating revenues	$	2,171		$	850		$	—		$	(92	)	$	2,929
Operating Costs and Expenses
Cost of operations	1,647			492			—			(88		)	2,051
Depreciation and amortization	207			103			3			—			313
Selling, general and administrative	110			66			58			(4		)	230
Acquisition-related transaction and integration costs	—			12			15			—			27
Development activity expenses	—			7			14			—			21
Total operating costs and expenses	1,964			680			90			(92		)	2,642
Operating Income/(Loss)	207			170			(90		)	—			287
Other Income/(Expense)
Equity in earnings/(losses) of consolidated subsidiaries	20			(2		)	208			(226		)	—
Equity in earnings of unconsolidated affiliates	1			4			—			3			8
Other income, net	1			(2		)	1			—			—
Loss on debt extinguishment	—			(11		)	(10		)	—			(21		)
Interest expense	(5		)	(77		)	(124		)	—			(206		)
Total other income/(expense)	17			(88		)	75			(223		)	(219		)
Income/Loss Before Income Taxes	224			82			(15		)	(223		)	68
Income tax expense/(benefit)	65			11			(139		)	—			(63		)
Net Income	159			71			124			(223		)	131
Less: Net income attributable to noncontrolling interest	—			4			—			3			7
Net Income attributable to NRG Energy, Inc.	$	159		$	67		$	124		$	(226	)	$	124
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Six Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Operating Revenues
Total operating revenues	$	3,761		$	1,375		$	—		$	(126	)	$	5,010
Operating Costs and Expenses
Cost of operations	2,905			1,007			7			(115		)	3,804
Depreciation and amortization	411			203			6			—			620
Selling, general and administrative	225			118			125			(11		)	457
Acquisition-related transaction and integration costs	—			41			28			—			69
Development activity expenses	—			13			26			—			39
Total operating costs and expenses	3,541			1,382			192			(126		)	4,989
Operating Income/(Loss)	220			(7		)	(192		)	—			21
Other Income/(Expense)
Equity in earnings/(losses) of consolidated subsidiaries	21			(4		)	44			(61		)	—
Equity in earnings of unconsolidated affiliates	2			6			—			3			11
Other income, net	2			—			2			—			4
Loss on debt extinguishment	—			(11		)	(38		)	—			(49		)
Interest expense	(10		)	(141		)	(251		)	—			(402		)
Total other income/(expense)	15			(150		)	(243		)	(58		)	(436		)
Income/(Loss) Before Income Taxes	235			(157		)	(435		)	(58		)	(415		)
Income tax expense/(benefit)	86			(74		)	(227		)	—			(215		)
Net Income/(Loss)	149			(83		)	(208		)	(58		)	(200		)
Less: Net income attributable to noncontrolling interest	—			5			—			3			8
Net Income/(Loss) attributable to NRG Energy, Inc.	$	149		$	(88	)	$	(208	)	$	(61	)	$	(208	)
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME
For the Three Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Net Income	$	159		$	71		$	124		$	(223	)	$	131
Other comprehensive (loss)/income, net of tax
Unrealized (loss)/gain on derivatives, net	(32		)	44			(15		)	20			17
Foreign currency translation adjustments, net	—			(15		)	(4		)	—			(19		)
Defined benefit plan	—			25			(5		)	—			20
Other comprehensive (loss)/income	(32		)	54			(24		)	20			18
Comprehensive income	127			125			100			(203		)	149
Less: Comprehensive income attributable to noncontrolling interest	—			9			—			(2		)	7
Comprehensive income attributable to NRG Energy, Inc.	127			116			100			(201		)	142
Dividends for preferred shares	—			—			3			—			3
Comprehensive income available for common stockholders	$	127		$	116		$	97		$	(201	)	$	139
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME/(LOSS)
For the Six Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Net Income/(Loss)	$	149		$	(83	)	$	(208	)	$	(58	)	$	(200	)
Other comprehensive (loss)/income, net of tax
Unrealized (loss)/gain on derivatives, net	(41		)	49			(8		)	24			24
Foreign currency translation adjustments, net	—			(15		)	(4		)	—			(19		)
Available-for-sale securities, net	—			—			2			—			2
Defined benefit plan	—			25			—			—			25
Other comprehensive (loss)/income	(41		)	59			(10		)	24			32
Comprehensive income/(loss)	108			(24		)	(218		)	(34		)	(168		)
Less: Comprehensive income attributable to noncontrolling interest	—			10			—			(2		)	8
Comprehensive income/(loss) attributable to NRG Energy, Inc.	108			(34		)	(218		)	(32		)	(176		)
Dividends for preferred shares	—			—			5			—			5
Comprehensive income/(loss) available for common stockholders	$	108		$	(34	)	$	(223	)	$	(32	)	$	(181	)
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
December 31, 2013
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	56		$	870		$	1,328		$	—		$	2,254
Funds deposited by counterparties	7			56			—			—			63
Restricted cash	12			252			4			—			268
Accounts receivable, net	965			249			—			—			1,214
Inventory	436			462			—			—			898
Derivative instruments	866			470			—			(8		)	1,328
Deferred income taxes	—			41			217			—			258
Cash collateral paid in support of energy risk management activities	214			62			—			—			276
Renewable energy grant receivable	—			539			—			—			539
Prepayments and other current assets	4,778			379			(3,802		)	(857		)	498
Total current assets	7,334			3,380			(2,253		)	(865		)	7,596
Net Property, Plant and Equipment	9,116			10,604			153			(22		)	19,851
Other Assets
Investment in subsidiaries	32			422			18,266			(18,720		)	—
Equity investments in affiliates	(30		)	583			—			(100		)	453
Capital leases and notes receivable, less current portion	—			62			105			(94		)	73
Goodwill	1,973			12			—			—			1,985
Intangible assets, net	925			232			4			(21		)	1,140
Nuclear decommissioning trust fund	551			—			—			—			551
Deferred income taxes				681			521			—			1,202
Derivative instruments	110			202			—			(1		)	311
Other non-current assets	76			281			383			—			740
Total other assets	3,637			2,475			19,279			(18,936		)	6,455
Total Assets	$	20,087		$	16,459		$	17,179		$	(19,823	)	$	33,902
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Current portion of long-term debt and capital leases	$	1		$	1,029		$	20		$	—		$	1,050
Accounts payable	652			352			34			—			1,038
Accounts payable — affiliate	1,350			760			(1,253		)	(857		)	—
Derivative instruments	859			204			—			(8		)	1,055
Cash collateral received in support of energy risk management activities	6			57			—			—			63
Accrued expenses and other current liabilities	297			410			291			—			998
Total current liabilities	3,165			2,812			(908		)	(865		)	4,204
Other Liabilities
Long-term debt and capital leases	317			7,837			7,707			(94		)	15,767
Nuclear decommissioning reserve	294			—			—			—			294
Nuclear decommissioning trust liability	324			—			—			—			324
Deferred income taxes	1,024			(1,002		)	—			—			22
Derivative instruments	147			49			—			(1		)	195
Out-of-market contracts	127			1,050			—			—			1,177
Other non-current liabilities	412			615			174			—			1,201
Total non-current liabilities	2,645			8,549			7,881			(95		)	18,980
Total liabilities	5,810			11,361			6,973			(960		)	23,184
3.625% Preferred Stock	—			—			249			—			249
Stockholders’ Equity	14,277			5,098			9,957			(18,863		)	10,469
Total Liabilities and Stockholders’ Equity	$	20,087		$	16,459		$	17,179		$	(19,823	)	$	33,902
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated Balance
							(Note Issuer)
	(In millions)
Cash Flows from Operating Activities
Net Cash Provided/(Used) by Operating Activities	$	664		$	(288	)	$	(844	)	$	390		$	(78	)
Cash Flows from Investing Activities
Intercompany loans to subsidiaries	(393		)	3			390			—			—
Acquisition of businesses, net of cash acquired	—			(39		)	—			—			(39		)
Capital expenditures	(196		)	(1,081		)	(4		)	—			(1,281		)
(Increase)/decrease in restricted cash, net	(2		)	(30		)	1			—			(31		)
Increase in restricted cash — U.S. DOE projects	—			(10		)	(6		)	—			(16		)
Decrease/(increase) in notes receivable	3			(6		)	(8		)	—			(11		)
Investments in nuclear decommissioning trust fund securities	(233		)	—			—			—			(233		)
Proceeds from sales of nuclear decommissioning trust fund securities	208			—			—			—			208
Proceeds from renewable energy grants	—			48			—			—			48
Other	(8		)	(12		)	—			—			(20		)
Net Cash (Used)/Provided by Investing Activities	(621		)	(1,127		)	373			—			(1,375		)
Cash Flows from Financing Activities
Proceeds from intercompany loans	—			—			390			(390		)	—
Payment of dividends to preferred stockholders	—			—			(73		)	—			(73		)
Payment for treasury stock	—			—			(25		)	—			(25		)
Net (payment for)/receipts from settlement of acquired derivatives that include financing elements	(49		)	220			—			—			171
Proceeds from issuance of long-term debt	—			995			477			—			1,472
Proceeds from issuance of common stock	—			—			9			—			9
Sale proceeds and other contributions from noncontrolling interest in subsidiaries	—			33			—			—			33
Payment of debt issuance costs	—			(7		)	(28		)	—			(35		)
Payments for short and long-term debt	—			(607		)	(209		)	—			(816		)
Net Cash (Used)/Provided by Financing Activities	(49		)	634			541			(390		)	736
Effect of exchange rate changes on cash and cash equivalents	—			(2		)	—			—			(2		)
Net (Decrease)/Increase in Cash and Cash Equivalents	(6		)	(783		)	70			—			(719		)
Cash and Cash Equivalents at Beginning of Period	78			1,258			751			—			2,087
Cash and Cash Equivalents at End of Period	$	72		$	475		$	821		$	—		$	1,368
(a)	All significant intercompany transactions have been eliminated in consolidation.

Basis_of_Presentation_Reclassi

Basis of Presentation Reclassifications (Policies)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Reclassification, Policy [Policy Text Block]	'
	Reclassifications
	Certain prior year amounts have been reclassified for comparative purposes. The reclassifications did not affect results from operations or cash flows.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policy)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Business Description and Basis of Presentation [Text Block]	'
	NRG Energy, Inc., or NRG or the Company, is a competitive power and energy company that produces, sells and delivers energy and energy services in major competitive power markets in the United States while positioning itself as a leader in the way residential, industrial and commercial consumers think about and use energy products and services. NRG owns and operates power generation facilities; engages in the trading of energy, capacity and related products; transacts in and trades fuel and transportation services and directly sells energy, services, and innovative, sustainable products to retail customers. The Company sells retail electricity products and services under the name “NRG” and various brands owned by NRG. Finally, NRG is a leader in the deployment and commercialization of potentially transformative technologies, like electric vehicles, Distributed Solar and smart meter/home automation technology that collectively have the potential to fundamentally change the nature of the power industry and the role of the national electric transmission grid and distribution system.
	The accompanying unaudited interim condensed consolidated financial statements have been prepared in accordance with the SEC's regulations for interim financial information and with the instructions to Form 10-Q. Accordingly, they do not include all of the information and notes required by generally accepted accounting principles for complete financial statements. The following notes should be read in conjunction with the accounting policies and other disclosures as set forth in the notes to the consolidated financial statements in the Company's 2013 Form 10-K. Interim results are not necessarily indicative of results for a full year.
	In the opinion of management, the accompanying unaudited interim condensed consolidated financial statements contain all material adjustments consisting of normal and recurring accruals necessary to present fairly the Company's consolidated financial position as of June 30, 2014, and the results of operations, comprehensive loss and cash flows for the three and six months ended June 30, 2014, and 2013.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	Recent Accounting Developments
	ASU 2014-09 - In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or ASU No. 2014-09. The amendments of ASU No. 2014-09 complete the joint effort between the FASB and the International Accounting Standards Board, or IASB, to develop a common revenue standard for U.S. GAAP and International Financial Reporting Standards, or IFRS, and to improve financial reporting. The guidance in ASU No. 2014-09 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for the goods or services provided and establishes the following steps to be applied by an entity: (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies the performance obligation. The guidance of ASU No. 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods therein. Early adoption is not permitted. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position.
	ASU 2013-11 - In July 2013, the FASB issued ASU No. 2013-11, Income Taxes (Topic 740) Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists, or ASU No. 2013-11.  The amendments of ASU No. 2013-11, which were adopted on January 1, 2014, require an entity to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, as a reduction of a deferred tax asset for a net operating loss, or NOL, a similar tax loss or tax credit carryforward rather than a liability when the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and the entity intends to use the deferred tax asset for that purpose.  The adoption of this standard did not impact the Company's results of operations or cash flows as the unrecognized tax benefits relate to state issues and the Company either has no NOL's or the NOL's are limited for that particular jurisdiction.
Cash Flow, Supplemental Disclosures [Text Block]	'
	Other Cash Flow Information
	NRG’s investing activities exclude capital expenditures of $127 million which were accrued and unpaid at June 30, 2014
Use of Estimates (Policy)	'
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. Certain prior period depreciation amounts have been recast to revise provisional purchase accounting estimates for the GenOn acquisition.
Nuclear Decommissioning (Policy)	'
	NRG's Nuclear Decommissioning Trust Fund assets are comprised of securities classified as available-for-sale and recorded at fair value based on actively quoted market prices. NRG accounts for the Nuclear Decommissioning Trust Fund in accordance with ASC 980, Regulated Operations, because the Company's nuclear decommissioning activities are subject to approval by the PUCT with regulated rates that are designed to recover all decommissioning costs and that can be charged to and collected from the ratepayers per PUCT mandate. Since the Company is in compliance with PUCT rules and regulations regarding decommissioning trusts and the cost of decommissioning is the responsibility of the Texas ratepayers, not NRG, all realized and unrealized gains or losses (including other-than-temporary impairments) related to the Nuclear Decommissioning Trust Fund are recorded to nuclear decommissioning trust liability and are not included in net income or accumulated other comprehensive income, consistent with regulatory treatment.
Segment Reporting (Policy)	'
	Effective June 2014, the Company's segment structure and its allocation of corporate expenses were updated to reflect how management currently makes financial decisions and allocates resources. The Texas and South Central segments were combined to form the Gulf Coast segment. The Company has recast data from prior periods to reflect this change in reportable segments to conform to the current year presentation. The Company's businesses are primarily segregated based on the Retail Business, conventional power generation, renewable businesses, NRG Yield and corporate activities.  Within NRG's conventional power generation, there are distinct components with separate operating results and management structures for the following geographical regions: Gulf Coast, East and West. The Company's renewables segment includes solar and wind assets, excluding those in the NRG Yield segment. NRG Yield includes certain of the Company's contracted generation assets including four natural gas or dual-fired facilities, ten utility-scale solar and wind generation facilities, two portfolios of distributed solar facilities and thermal infrastructure assets. On June 30, 2014, NRG Yield acquired three projects from the Company: El Segundo Energy Center, formerly in the West segment, Kansas South and High Desert, both formerly in the renewables segment. As the transaction was accounted for as a transfer of entities under common control, all historical periods have been recast to reflect this change. The Company's corporate segment includes international business, electric vehicle services, energy services, residential solar and the carbon capture business. Intersegment sales are accounted for at market.

Basis_of_Presentation_Use_of_E

Basis of Presentation Use of Estimates (Policies)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Use of Estimates (Policy)	'
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. Certain prior period depreciation amounts have been recast to revise provisional purchase accounting estimates for the GenOn acquisition.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Schedule of Change in Noncontrolling Interest	'
	Noncontrolling Interest
	The following table reflects the changes in NRG's noncontrolling interest balance:
		(In millions)
	Balance as of December 31, 2013	$	867
	Acquisition of EME	380
	Sale of assets to NRG Yield, Inc.	(41		)
	Non-cash adjustments for equity component of NRG Yield, Inc. convertible notes	23
	Non-cash adjustments to noncontrolling interest	(76		)
	Contributions from noncontrolling interest	25
	Distributions to noncontrolling interest	(15		)
	Comprehensive loss attributable to noncontrolling interest	(3		)
	Balance as of June 30, 2014	$	1,160

Business_Acquisitions_and_Disp1

Business Acquisitions and Dispositions (Tables)	6 Months Ended
	Jun. 30, 2014
Business Acquisition [Line Items]	'
Acquisitions and Dispositions [Text Block]	'
	Business Acquisitions and Dispositions
	Disposition of 50% Interest in Petra Nova Parish Holdings LLC
	On July 3, 2014, the Company, through its wholly owned subsidiary Petra Nova Holdings LLC, sold 50% of its interest in Petra Nova Parish Holdings LLC to JX Nippon Oil Exploration (EOR) Limited, a wholly owned subsidiary of JX Nippon Oil & Gas Exploration Corporation.  As a result of the sale, the Company no longer has a controlling interest in and has deconsolidated Petra Nova Parish Holdings LLC as of the date of the sale. On July 7, 2014, the Company made its initial capital contribution into the partnership of $35 million, which was funded with the sale proceeds of $76 million. On March 3, 2014, Petra Nova CCS I LLC, a wholly owned subsidiary of Petra Nova Parish Holdings LLC, entered into a fixed-price agreement to build and operate a CCS-EOR at the W.A. Parish facility with a consortium of Mitsubishi Heavy Industries America, Inc. and TIC - The Industrial Company.  Notice to proceed for the construction on the CCS-EOR was issued on July 15, 2014, and commercial operation is expected in late 2016.
	The joint venture also owns a 75 MW peaking unit at W.A. Parish, which achieved commercial operations on June 26, 2013. The peaking unit will be converted into a cogeneration facility to provide power and steam to the CCS-EOR.  The CCS-EOR is being financed by: (i) up to $167 million from a U.S. DOE CCPI grant of which $7 million has already been received from the grant in the initial design and engineering phase, (ii) $250 million in loans provided by the Japan Bank for International Cooperation and Mizuho Bank, Ltd., and (iii) approximately $300 million in equity contributions from each of the Company and JX Nippon. The Company’s contribution will include investments already made during the development of the project.
	On July 14, 2014, Petra Nova Parish Holdings LLC entered into two credit facilities, or the Petra Nova Parish Credit Agreements, to fund the cost of construction of the CCS-EOR at the W.A. Parish facility. The Petra Nova Parish Credit Agreements are comprised of a $75 million Nippon Export and Investment Insurance, or NEXI, covered loan and a $175 million Japan Bank for International Cooperation, or JBIC, facility. The NEXI covered loan has an interest rate of LIBOR plus an applicable margin of 1.75% and the JBIC facility has an interest rate of LIBOR plus an applicable margin of 0.50% during the construction phase which escalates to an applicable margin of 1.50% upon completion of the CCS-EOR. Both credit facilities mature in April 2026. NRG has guaranteed its 50% share of the obligations under the Petra Nova Parish Credit Agreements.
	Sales of Assets to NRG Yield, Inc.
	On June 30, 2014, the Company sold the following facilities to NRG Yield, Inc.: High Desert, Kansas South, and El Segundo Energy Center. NRG Yield, Inc. paid total cash consideration of $357 million, which represents a base purchase price of $349 million and $8 million of working capital adjustments, plus assumed project level debt of approximately $612 million. The sale was recorded as a transfer of entities under common control and the related assets were transferred at carrying value.
	Pending Acquisition
	On June 3, 2014, NRG Yield Operating LLC, or Yield Operating, a consolidated subsidiary of the Company, entered into a purchase and sale agreement with Terra-Gen Finance Company, LLC and certain of its affiliates to acquire 100% of the membership interests of Alta Wind Asset Management Holdings, LLC, Alta Wind Company, LLC, Alta Wind X Holding Company, LLC, and Alta Wind XI Holding Company, LLC, which collectively owns seven wind facilities that total 947 MWs located in Tehachapi, California and a portfolio of land leases, or the Alta Wind Assets. The purchase price of the Alta Wind Assets is $870 million, as well as working capital adjustments, plus the assumption of $1.6 billion in non-recourse project level debt. The acquisition, which is subject to customary closing conditions, including certain regulatory approvals, is expected to close during the third quarter of 2014. Power generated by the Alta Wind facility is sold to Southern California Edison under long-term power purchase agreements with 21 years of remaining contract life for Phases I-V and 22 years, beginning in 2016, for Phases X and XI.
	In order to fund the purchase price of the acquisition, NRG Yield, Inc. issued 12,075,000 shares of its Class A common stock on July 29,2014 for net proceeds of $630 million. In addition, on August 5, 2014, Yield Operating issued $500 million in aggregate principal amount at par of 5.375% senior notes due August 2024. Interest on the notes is payable semi-annually on February 15 and August 15 of each year, commencing on February 15, 2015. The notes are senior unsecured obligations of Yield Operating and are guaranteed by NRG Yield LLC, Yield Operating’s parent company, and by certain of Yield Operating’s wholly owned current and future subsidiaries.
	Acquisition of Dominion's Competitive Electric Retail Business
	On March 31, 2014, the Company acquired the competitive retail electricity business of Dominion Resources, Inc., or Dominion. The acquisition of Dominion's competitive retail electricity business increased NRG’s retail portfolio by approximately 217,000 customers as of June 30, 2014, and is expected to increase NRG’s retail portfolio by approximately 500,000 customers in the aggregate by the end of 2014. The acquisition supports NRG's ongoing efforts to expand the Company's retail footprint in the Northeast and to grow its retail position in Texas. The Company paid approximately $195 million as cash consideration for the acquisition, including $165 million of purchase price and $30 million paid for working capital balances, which was funded by cash on hand. The purchase price was provisionally allocated to the following: $50 million to accounts receivable-trade, $62 million to customer relationships, $9 million to trade names, $10 million to current assets, $20 million to derivative assets, $46 million to current and non-current liabilities, and goodwill of $90 million which is not deductible for U.S. income tax purposes in future periods. The factors that resulted in goodwill arising from the acquisition include the revenues associated with new customers in new regions and through the synergies associated with combining a new retail business with the Company's generation assets. The acquired assets and liabilities are included within the Retail segment. The provisional amounts are subject to revision until the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date. Any changes to the fair value assessments will affect the value of goodwill. The allocation of the purchase price may be modified up to one year from the date of the acquisition as more information is obtained about the fair value of assets acquired and liabilities assumed.
	EME Acquisition
	On April 1, 2014, the Company acquired substantially all of the assets of EME.  EME, through its subsidiaries and affiliates, owned or leased and operated a portfolio of approximately 8,000 MW consisting of wind energy facilities and coal- and gas-fired generating facilities. The Company paid an aggregate purchase price of $3.5 billion, which was comprised of the following:
		Original Purchase Price			Purchase Price on Acquisition Date
	Cash and equivalents (a)	$	2,285		$	3,021
	Common shares (b)	350			401
	Liabilities acquired	—			71
	Total purchase price	2,635			3,493
	Less: cash acquired				1,422
	Net purchase price				$	2,071
	(a) The increase in cash paid relates to an increase in acquired cash on hand as well as changes in cash collateral, restricted cash and cash related to unconsolidated subsidiaries. It also reflects lease and debt payments in 2014.
	(b) The increase in the value of the common shares reflects an increase in trading price of NRG common shares between October 18, 2013 and April 1, 2014. The shares of NRG common stock were given a value of $350 million in determining the cash purchase price, which was based upon the volume-weighted average trading price over the 20 trading days prior to October 18, 2013.
	The purchase price was funded through the issuance of 12,671,977 shares of NRG common stock on April 1, 2014, the issuance of $700 million in newly-issued corporate debt, as described in Note 7, Debt and Capital Leases, and cash on hand. The Company also assumed non-recourse debt of approximately $1.2 billion.
	In connection with the transaction, NRG agreed to certain conditions with the parties to the Powerton and Joliet, or POJO, sale-leaseback transaction subject to which an NRG subsidiary assumed the POJO leveraged leases and NRG guaranteed the remaining payments under each lease, which total $485 million through 2034. In connection with this agreement, NRG has committed to fund up to $350 million in capital expenditures for plant modifications at Powerton and Joliet to comply with environmental regulations, as discussed further in Note 15, Environmental Matters. In addition, NRG assumed certain long-term contractual arrangements for fuel and transportation. Commitments under these arrangements totaled approximately $490 million.
	On April 30, 2014, subsequent to the acquisition, the Company acquired the remaining 50% ownership of Mission Del Sol LLC, which owns the Sunrise facility, a 586 MW natural gas facility in Fellows, California, from Chevron increasing the Company's ownership interest to 100% in exchange for the Company's 50% interest in six cogeneration facilities, previously co-owned with Chevron.
	The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The initial accounting for the business combination is not complete because the evaluation necessary to assess the fair values of certain net assets acquired is still in process. The provisional amounts are subject to revision until the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date. The allocation of the purchase price may be modified up to one year from the date of the acquisition as more information is obtained about the fair value of assets acquired and liabilities assumed. The purchase price of $3.5 billion was provisionally allocated as follows:
			(In millions)
	Assets
	Cash		$	1,422
	Current assets		676
	Property, plant and equipment		2,475
	Intangible assets		312
	Non-current assets		813
	Total assets acquired		5,698
	Liabilities
	Current and non-current liabilities		533
	Out-of-market contracts and leases		43
	Long-term debt		1,249
	Total liabilities assumed		1,825
	Less: noncontrolling interest		380
	Net assets acquired		$	3,493
	The Company incurred and expensed acquisition-related transaction costs of $14 million and $17 million for the three and six months ended June 30, 2014.
	Fair value measurements
	The provisional fair values of the property, plant and equipment, intangible assets and out-of-market contracts at the acquisition date were measured primarily based on significant inputs that are not observable in the market and thus represent a Level 3 measurement as defined in ASC 820. Significant inputs were as follows:
	Property, plant and equipment - The estimated fair values were determined primarily based on an income method using discounted cash flows and validated using a market approach based on recent transactions of comparable assets. The income approach was primarily relied upon as the forecasted cash flows more appropriately incorporate differences in regional markets, plant types, age, useful life, equipment condition and environmental controls of each asset. The income approach also allows for a more accurate reflection of current and expected market dynamics such as supply and demand, commodity prices and regulatory environment as of the acquisition date.
	Intangible assets - The fair values of the PPAs acquired were determined utilizing a variation of the income approach where the expected future cash flows resulting from the acquired PPAs were reduced by operating costs and charges for contributory assets and then discounted to present value at the weighted average cost of capital of an integrated utility peer group adjusted for project-specific financing attributes. The values were corroborated with available market data.
	Out-of-market lease contracts - The estimated fair values of the acquired leases were determined utilizing a variation of the income approach under which the fair value of the lease was determined by discounting the future lease payments at an appropriate discount rate and comparing it to the fair value of the property, plant and equipment being leased.
	Noncontrolling interest - The estimated fair value of the noncontrolling interests represent the fair value of the partners' contributions as of the acquisition date.
	Supplemental Pro Forma Information
	Since the acquisition date, EME contributed $311 million in operating revenues and $14 million in net losses attributable to NRG. The following supplemental pro forma information represents the results of operations as if NRG had acquired EME on January 1, 2013:
			For the six months ended							For the year ended
	(in millions except per share amounts)		30-Jun-14				30-Jun-13			31-Dec-13
	Operating revenues		$	7,655			$	5,618		$	12,598
	Net loss attributable to NRG Energy, Inc.		(136		)		(390		)	(1,009		)
	Loss per share attributable to NRG common stockholders:
	Basic		(0.41		)		(1.16		)	(3.00		)
	Diluted		(0.41		)		(1.16		)	(3.00		)
	The supplemental pro forma information has been adjusted to include the pro-forma impact of depreciation of property, plant and equipment, amortization of lease obligations and out-of-market contracts, based on the preliminary purchase price allocations. The pro forma data has also been adjusted to eliminate non-recurring transaction costs incurred by NRG, as well as the related tax impact. There were no transactions during the periods between NRG and EME. The pro forma results are presented for illustrative purposes only and do not reflect the realization of potential cost savings or any related integration costs. The Company expects to achieve certain cost savings from the acquisition; however, there can be no assurance that these cost savings will be achieved.
	2013 Acquisitions
	Energy Systems Acquisition
	On December 31, 2013, NRG Energy Center Omaha Holdings, LLC, an indirect wholly owned subsidiary of NRG Yield LLC, acquired 100% of Energy Systems Company, or Energy Systems, for approximately $120 million. The acquisition was financed from cash on hand. Energy Systems is an operator of steam and chilled thermal facilities that provides heating and cooling services to nonresidential customers in Omaha, Nebraska. The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The purchase price was primarily allocated to property, plant and equipment of $60 million, customer relationships of $59 million, and working capital of $1 million. The initial accounting for the business combination is not complete because the evaluations necessary to assess the fair values of certain net assets acquired and the amount of goodwill to be recognized are still in process. The provisional amounts are subject to revision until the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date.
	Gregory Acquisition
On August 7, 2013, NRG Texas Gregory, LLC, a wholly owned subsidiary of NRG, acquired Gregory Power Partners, L.P. for approximately $245 million in cash, net of $32 million cash acquired. Gregory is a cogeneration plant located in Corpus Christi, Texas, which has generation capacity of 388 MW and steam capacity of 160 MWt. The Gregory cogeneration plant provides steam, processed water and a small percentage of its electrical generation to the Corpus Christi Sherwin Alumina plant. The majority of the plant's generation is available for sale in the ERCOT market. The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The purchase price was provisionally allocated primarily to property, plant, and equipment of $248 million, current assets of $13 million, and other liabilities of $16 million. The accounting for the Gregory acquisition was completed as of June 30, 2014, at which point the provisional fair values became final with no material changes.
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	The purchase price of $3.5 billion was provisionally allocated as follows:
			(In millions)
	Assets
	Cash		$	1,422
	Current assets		676
	Property, plant and equipment		2,475
	Intangible assets		312
	Non-current assets		813
	Total assets acquired		5,698
	Liabilities
	Current and non-current liabilities		533
	Out-of-market contracts and leases		43
	Long-term debt		1,249
	Total liabilities assumed		1,825
	Less: noncontrolling interest		380
	Net assets acquired		$	3,493
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The following supplemental pro forma information represents the results of operations as if NRG had acquired EME on January 1, 2013:
			For the six months ended							For the year ended
	(in millions except per share amounts)		30-Jun-14				30-Jun-13			31-Dec-13
	Operating revenues		$	7,655			$	5,618		$	12,598
	Net loss attributable to NRG Energy, Inc.		(136		)		(390		)	(1,009		)
	Loss per share attributable to NRG common stockholders:
	Basic		(0.41		)		(1.16		)	(3.00		)
	Diluted		(0.41		)		(1.16		)	(3.00		)

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value of Financial Instruments Disclosure [Abstract]	'
Estimated carrying amounts and fair values of NRG's recorded financial instruments not carried at fair market value	'
	The estimated carrying amounts and fair values of NRG's recorded financial instruments not carried at fair market value are as follows:
		As of June 30, 2014					As of December 31, 2013
		Carrying Amount		Fair Value			Carrying Amount			Fair Value
		(In millions)
	Assets:
	Notes receivable (a)	$	114	$	114		$	99		$	99
	Liabilities:
	Long-term debt, including current portion	18,988		19,576			16,804			17,222
	(a) Includes the current portion of notes receivable which is recorded in prepayments and other current assets on the Company's consolidated balance sheets.
Assets and liabilities measured and recorded at fair value on the consolidated balance sheets on a recurring basis	'
	The following tables present assets and liabilities measured and recorded at fair value on the Company's condensed consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:
		As of June 30, 2014
		Fair Value
	(In millions)	Level 1		Level 2			Level 3			Total
	Investment in available-for-sale securities (classified within other
	non-current assets):
	Debt securities	$	—	$	—		$	18		$	18
	Available-for-sale securities	14		—			—			14
	Other (a)	21		—			11			32
	Nuclear trust fund investments:
	Cash and cash equivalents	3		—			—			3
	U.S. government and federal agency obligations	37		4			—			41
	Federal agency mortgage-backed securities	—		62			—			62
	Commercial mortgage-backed securities	—		26			—			26
	Corporate debt securities	—		92			—			92
	Equity securities	292		—			58			350
	Foreign government fixed income securities	—		2			—			2
	Other trust fund investments:
	U.S. government and federal agency obligations	1		—			—			1
	Derivative assets:
	Commodity contracts	315		1,438			353			2,106
	Interest rate contracts	—		8			—			8
	Total assets	$	683	$	1,632		$	440		$	2,755
	Derivative liabilities:
	Commodity contracts	$	235	$	1,349		$	365		$	1,949
	Interest rate contracts	—		141			—			141
	Total liabilities	$	235	$	1,490		$	365		$	2,090
	(a) Primarily consists of mutual funds held in rabbi trusts for non-qualified deferred compensation plans for certain former employees.
		As of December 31, 2013
		Fair Value
	(In millions)	Level 1		Level 2			Level 3			Total
	Investment in available-for-sale securities (classified within other
	non-current assets):
	Debt securities	$	—	$	—		$	16		$	16
	Available-for-sale securities	2		—			—			2
	Other (a)	37		—			10			47
	Nuclear trust fund investments:
	Cash and cash equivalents	26		—			—			26
	U.S. government and federal agency obligations	40		5			—			45
	Federal agency mortgage-backed securities	—		62			—			62
	Commercial mortgage-backed securities	—		14			—			14
	Corporate debt securities	—		70			—			70
	Equity securities	276		—			56			332
	Foreign government fixed income securities	—		2			—			2
	Other trust fund investments:
	U.S. government and federal agency obligations	1		—			—			1
	Derivative assets:
	Commodity contracts	346		1,126			147			1,619
	Interest rate contracts	—		20			—			20
	Total assets	$	728	$	1,299		$	229		$	2,256
	Derivative liabilities:
	Commodity contracts	$	216	$	831		$	134		$	1,181
	Interest rate contracts	—		69			—			69
	Total liabilities	$	216	$	900		$	134		$	1,250
	(a) Primarily consists of mutual funds held in rabbi trusts for non-qualified deferred compensation plans for certain former employees.
Reconciliation of beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements at least annually using significant unobservable inputs	'
	The following tables reconcile, for the three and six months ended June 30, 2014 and 2013, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements, at least annually, using significant unobservable inputs:
		Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
		Three months ended June 30, 2014														Six months ended June 30, 2014
	(In millions)	Debt Securities		Other			Trust Fund Investments			Derivatives(a)			Total			Debt Securities		Other			Trust Fund Investments			Derivatives(a)			Total
	Beginning balance	$	18	$	11		$	56		$	23		$	108		$	16	$	10		$	56		$	13		$	95
	Total gains/(losses) — realized/unrealized:
	Included in earnings	—		—			—			(12		)	(12		)	—		1			—			4			5
	Included in OCI	—		—			—			—			—			2		—			—			—			2
	Included in nuclear	—		—			1			—			1			—		—			1			—			1
	decom-
	missioning
	obligation
	Purchases	—		—			1			(63		)	(62		)	—		—			1			(84		)	(83		)
	Contracts acquired in Dominion and EME acquisition	—		—			—			36			36			—		—			—			39			39
	Transfers into Level 3 (b)	—		—			—			—			—			—		—			—			18			18
	Transfers out of Level 3 (b)	—		—			—			4			4			—		—			—			(2		)	(2		)
	Ending balance as of June 30, 2014	$	18	$	11		$	58		$	(12	)	$	75		$	18	$	11		$	58		$	(12	)	$	75
	Gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of June 30, 2014	$	—	$	—		$	—		$	2		$	2		$	—	$	—		$	—		$	21		$	21
	(a)	Consists of derivative assets and liabilities, net.
	(b)	Transfers in/out of Level 3 are related to the availability of external broker quotes and are valued as of the end of the reporting period. All transfers in/out are with Level 2.
		Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
		Three months ended June 30, 2013											Six months ended June 30, 2013
	(In millions)	Debt Securities		Trust Fund Investments			Derivatives(a)			Total			Debt Securities			Trust Fund Investments		Derivatives(a)			Total
	Beginning balance	$	13	$	50		$	5		$	68		$	12		$	47	$	(12	)	$	47
	Total (losses)/gains — realized/unrealized:
	Included in earnings	—		—			9			9			—			—		(18		)	(18		)
	Included in OCI	2		—			—			2			3			—		—			3
	Included in nuclear decom-	—		(1		)	—			(1		)	—			2		—			2
	missioning obligations
	Purchases	—		1			(6		)	(5		)	—			1		(7		)	(6		)
	Transfers into Level 3 (b)	—		—			12			12			—			—		27			27
	Transfers out of Level 3 (b)	—		—			(32		)	(32		)	—			—		(2		)	(2		)
	Ending balance as of June 30, 2013	$	15	$	50		$	(12	)	$	53		$	15		$	50	$	(12	)	$	53
	Gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of June 30, 2013	—		—			24			24			—			—		3			3
	(a)	Consists of derivative assets and liabilities, net.
	(b)	Transfers in/out of Level 3 are related to the availability of external broker quotes and are valued as of the end of the reporting period. All transfers in/out are with Level 2.
Net counterparty credit exposure by industry sector and by counterparty credit quality	'
	The following tables highlight net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market and NPNS, and non-derivative transactions. The exposure is shown net of collateral held, and includes amounts net of receivables or payables.
		Net Exposure (a)
	Category	(% of Total)
	Financial institutions	34	%
	Utilities, energy merchants, marketers and other	31
	ISOs	30
	Coal and emissions	5
	Total as of June 30, 2014	100	%
		Net Exposure (a)
	Category	(% of Total)
	Investment grade	90	%
	Non-rated (b)	6
	Non-investment grade	4
	Total as of June 30, 2014	100	%
	(a)	Counterparty credit exposure excludes uranium and coal transportation contracts because of the unavailability of market prices.
	(b)	For non-rated counterparties, a significant portion are related to ISO and municipal public power entities, which are considered investment grade equivalent ratings based on NRG's internal credit ratings.

Nuclear_Decommissioning_Trust_1

Nuclear Decommissioning Trust Fund (Tables)	6 Months Ended
	Jun. 30, 2014
Nuclear Decommissioning Trust Fund Disclosure [Abstract]	'
Summary of aggregate fair values and unrealized gains and losses (including other-than-temporary impairments) for the securities held in the nuclear decommissioning trust fund	'
	The following table summarizes the aggregate fair values and unrealized gains and losses (including other-than-temporary impairments) for the securities held in the trust funds, as well as information about the contractual maturities of those securities.
		As of June 30, 2014							As of December 31, 2013
	(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted-average Maturities (In years)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted-average Maturities (In years)
	Cash and cash equivalents	$	3	$	—	$	—	—	$	26	$	—	$	—	—
	U.S. government and federal agency obligations	41		2		—		9	45		1		1		9
	Federal agency mortgage-backed securities	62		1		1		25	62		1		1		24
	Commercial mortgage-backed securities	26		—		—		30	14		—		—		29
	Corporate debt securities	92		3		—		11	70		1		1		9
	Equity securities	350		219		—		—	332		204		—		—
	Foreign government fixed income securities	2		—		—		16	2		—		—		9
	Total	$	576	$	225	$	1		$	551	$	207	$	3
Summary of proceeds from sales of available-for-sale securities and the related realized gains and losses	'
	The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from these sales. The cost of securities sold is determined on the specific identification method.
		Six months ended June 30,
		2014		2013
		(In millions)
	Realized gains	$	7	$	3
	Realized losses	3		4
	Proceeds from sale of securities	334		208

Accounting_for_Derivative_Inst1

Accounting for Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity	'
	The following table summarizes the net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity, excluding those derivatives that qualified for the NPNS exception as of June 30, 2014 and December 31, 2013. Option contracts are reflected using delta volume. Delta volume equals the notional volume of an option adjusted for the probability that the option will be in-the-money at its expiration date.
			Total Volume
			June 30, 2014				December 31, 2013
	Commodity	Units	(In millions)
	Emissions	Short Ton	1				—
	Coal	Short Ton	70				51
	Natural Gas	MMBtu	(239		)		(166		)
	Oil	Barrel	—				1
	Power	MWh	(43		)		(27		)
	Interest	Dollars	$	2,569			$	1,444
Fair value within the derivative instrument valuation on the balance sheets	'
	The following table summarizes the fair value within the derivative instrument valuation on the balance sheets:
		Fair Value
		Derivative Assets								Derivative Liabilities
		June 30, 2014				December 31, 2013				June 30, 2014				December 31, 2013
		(In millions)
	Derivatives designated as cash flow hedges:
	Interest rate contracts current	$	—			$	—			$	59			$	35
	Interest rate contracts long-term	7				14				74				29
	Commodity contracts current	—				—				—				1
	Commodity contracts long-term	—				—				—				1
	Total derivatives designated as cash flow hedges	7				14				133				66
	Derivatives not designated as cash flow hedges:
	Interest rate contracts current	—				—				5				4
	Interest rate contracts long-term	1				6				3				1
	Commodity contracts current	1,701				1,328				1,672				1,015
	Commodity contracts long-term	405				291				277				164
	Total derivatives not designated as cash flow hedges	2,107				1,625				1,957				1,184
	Total derivatives	$	2,114			$	1,639			$	2,090			$	1,250
Offsetting of derivatives by counterparty master agreement level and collateral received or paid	'
	The following table summarizes the offsetting of derivatives by counterparty master agreement level and collateral received or paid:
			Gross Amounts Not Offset in the Statement of Financial Position
			Gross Amounts of Recognized Assets / Liabilities				Derivative Instruments				Cash Collateral (Held) / Posted				Net Amount
	As of June 30, 2014		(In millions)
	Commodity contracts:
	Derivative assets		$	2,106			$	(1,706	)		$	(4	)		$	396
	Derivative liabilities		(1,949		)		1,706				75				(168		)
	Total commodity contracts		157				—				71				228
	Interest rate contracts:
	Derivative assets		8				(6		)		—				2
	Derivative liabilities		(141		)		6				—				(135		)
	Total interest rate contracts		(133		)		—				—				(133		)
	Total derivative instruments		$	24			$	—			$	71			$	95
			Gross Amounts Not Offset in the Statement of Financial Position
			Gross Amounts of Recognized Assets / Liabilities				Derivative Instruments				Cash Collateral (Held) / Posted				Net Amount
	As of December 31, 2013		(In millions)
	Commodity contracts:
	Derivative assets		$	1,619			$	(1,032	)		$	(62	)		$	525
	Derivative liabilities		(1,181		)		1,032				18				(131		)
	Total commodity contracts		438				—				(44		)		394
	Interest rate contracts:
	Derivative assets		20				(12		)		—				8
	Derivative liabilities		(69		)		12				—				(57		)
	Total interest rate contracts		(49		)		—				—				(49		)
	Total derivative instruments		$	389			$	—			$	(44	)		$	345
Effects of ASC 815 on the Company's accumulated OCI balance attributable to cash flow hedge derivatives, net of tax	'
	The following table summarizes the effects of ASC 815 on the Company's accumulated OCI balance attributable to cash flow hedge derivatives, net of tax:
		Three months ended June 30, 2014												Six months ended June 30, 2014
		Energy Commodities				Interest Rate				Total				Energy Commodities				Interest Rate			Total
		(In millions)
	Accumulated OCI beginning balance	$	(1	)		$	(31	)		$	(32	)		$	(1	)		$	(22	)	$	(23	)
	Reclassified from accumulated OCI to income:
	Due to realization of previously deferred amounts	—				(7		)		(7		)		—				(8		)	(8		)
	Mark-to-market of cash flow hedge accounting contracts	—				(12		)		(12		)		—				(20		)	(20		)
	Accumulated OCI ending balance, net of $29 tax	$	(1	)		$	(50	)		$	(51	)		$	(1	)		$	(50	)	$	(51	)
	Losses expected to be realized from OCI during the next 12 months, net of $7 tax	$	(1	)		$	(12	)		$	(13	)		$	(1	)		$	(12	)	$	(13	)
		Three months ended June 30, 2013												Six months ended June 30, 2013
		Energy Commodities				Interest Rate				Total				Energy Commodities				Interest Rate			Total
		(In millions)
	Accumulated OCI beginning balance	$	42			$	(66	)		$	(24	)		$	41			$	(72	)	$	(31	)
	Reclassified from accumulated OCI to income:
	Due to realization of previously deferred amounts	(15		)		1				(14		)		(23		)		4			(19		)
	Mark-to-market of cash flow hedge accounting contracts	(3		)		34				31				6				37			43
	Accumulated OCI ending balance, net of $4 tax	$	24			$	(31	)		$	(7	)		$	24			$	(31	)	$	(7	)
	Gains/(losses) expected to be realized from OCI during the next 12 months, net of $10 tax	$	26			$	(9	)		$	17			$	26			$	(9	)	$	17
	Losses recognized in income from the ineffective portion of cash flow hedges	$	—			$	(1	)		$	(1	)		$	(1	)		$	—		$	(1	)
Pre-tax effects of economic hedges that have not been designated as cash flow hedges, ineffectiveness on cash flow hedges and trading activity on the Company's statement of operations	'
	The following table summarizes the pre-tax effects of economic hedges that have not been designated as cash flow hedges, ineffectiveness on cash flow hedges and trading activity on the Company's statement of operations. The effect of commodity hedges is included within operating revenues and cost of operations and the effect of interest rate hedges is included in interest expense.
		Three months ended June 30,								Six months ended June 30,
		2014				2013				2014				2013
	Unrealized mark-to-market results	(In millions)
	Reversal of previously recognized unrealized gains on settled positions related to economic hedges	$	(5	)		$	(7	)		$	(2	)		$	(32	)
	Reversal of gain positions acquired as part of the GenOn and EME acquisitions	(84		)		(99		)		(162		)		(187		)
	Net unrealized (losses)/gains on open positions related to economic hedges	(30		)		204				(223		)		55
	Losses on ineffectiveness associated with open positions treated as cash flow hedges	—				—				—				(1		)
	Total unrealized mark-to-market (losses)/gains for economic hedging activities	(119		)		98				(387		)		(165		)
	Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	5				(1		)		5				(29		)
	Reversal of (gain)/loss positions acquired as part of the GenOn and EME acquisitions	(19		)		2				(20		)		—
	Net unrealized gains/(losses) on open positions related to trading activity	14				(13		)		30				(26		)
	Total unrealized mark-to-market (losses)/gains for trading activity	—				(12		)		15				(55		)
	Total unrealized (losses)/gains	$	(119	)		$	86			$	(372	)		$	(220	)
		Three months ended June 30,								Six months ended June 30,
		2014				2013				2014				2013
		(In millions)
	Unrealized (losses)/gains included in operating revenues	$	(48	)		$	181			$	(364	)		(340		)
	Unrealized (losses)/gains included in cost of operations	(71		)		(95		)		(8		)		120
	Total impact to statement of operations — energy commodities	$	(119	)		$	86			$	(372	)		$	(220	)
	Total impact to statement of operations — interest rate contracts	$	(3	)		$	4			$	(7	)		$	6

Debt_and_Capital_Leases_Debt_a

Debt and Capital Leases Debt and Capital Leases (Tables)	6 Months Ended
	Jun. 30, 2014
Long Term Debt Disclosure [Abstract]	'
Long-term debt and capital leases	'
	Long-term debt and capital leases consisted of the following:
	(In millions, except rates)	June 30, 2014			December 31, 2013			Current interest rate % (a)
	Recourse debt:
	Senior notes, due 2018	$	1,130		$	1,130		7.625
	Senior notes, due 2019	—			800			7.625
	Senior notes, due 2019	223			602			8.5
	Senior notes, due 2020	1,063			1,062			8.25
	Senior notes, due 2021	1,128			1,128			7.875
	Senior notes, due 2022	1,100			—			6.25
	Senior notes, due 2023	990			990			6.625
	Senior notes, due 2024	1,000			—			6.25
	Term loan facility, due 2018	1,992			2,002			L+2.00
	Indian River Power LLC, tax-exempt bonds, due 2040 and 2045	247			247			5.375 - 6.00
	Dunkirk Power LLC, tax-exempt bonds, due 2042	59			59			5.875
	Fort Bend County, tax-exempt bonds, due 2038, 2042, and 2045	67			67			4.75
	Subtotal NRG recourse debt	8,999			8,087
	Non-recourse debt:
	GenOn senior notes, due 2017	774			782			7.875
	GenOn senior notes, due 2018	769			780			9.5
	GenOn senior notes, due 2020	616			621			9.875
	GenOn Americas Generation senior notes, due 2021	499			503			8.5
	GenOn Americas Generation senior notes, due 2031	434			435			9.125
	Subtotal GenOn debt (non-recourse to NRG)	3,092			3,121
	NRG Marsh Landing, due 2017 and 2023	464			473			L+2.75 - 3.00
	NRG Energy Center Minneapolis LLC, due 2017 and 2025	124			127			5.95 - 7.25
	NRG Solar Alpine LLC, due 2022	170			221			L+2.50/L+1.75
	NRG Solar Borrego I LLC, due 2024 and 2038	77			78			L+2.50/5.65
	NRG West Holdings LLC, due 2023	520			512			L+2.50 - 2.875
	NRG Yield Inc. Convertible Senior Notes, due 2019	324			—			3.5
	NRG Yield - other	320			372			various
	Subtotal NRG Yield debt (non-recourse to NRG)	1,999			1,783
	CVSR High Plains Ranch II LLC, due 2037	798			1,104			2.339 - 3.775
	Agua Caliente Solar LLC, due 2037	923			878			2.395 - 3.633
	Ivanpah Financing, due 2014, 2015, 2033 and 2038	1,595			1,575			0.437 - 4.256
	NRG Peaker Finance Co. LLC, bonds due 2019	128			154			L+1.07
	Tapestry Wind LLC, due 2021	196			—			L+2.50
	Walnut Creek, term loans due 2023	409			—			L+2.25
	Viento Funding II, Inc., due 2023	198			—			L+2.75
	Cedro Hill Wind LLC, due 2025	113			—			L+3.125
	NRG - other	538			102			various
	Subtotal NRG non-recourse debt	4,898			3,813
	Subtotal non-recourse debt (including GenOn and NRG Yield)	9,989			8,717
	Subtotal long-term debt (including current maturities)	18,988			16,804
	Capital leases:
	Chalk Point capital lease, due 2015	7			10			8.19
	Other	3			3			various
	Subtotal long-term debt and capital leases (including current maturities)	18,998			16,817
	Less current maturities	833			1,050
	Total long-term debt and capital leases	$	18,165		$	15,767
	(a) As of June 30, 2014, L+ equals 3 month LIBOR plus x%, with the exception of the NRG Solar Kansas South LLC and Viento Funding II term loan which is 6 month LIBOR plus x%.
Schedule of Project level debt assumed during acquisition [Table Text Block]	'
	The following table summarizes the terms of the significant non-recourse project level debt assumed by NRG in the EME acquisition:
	Amount in millions, except rates	Term Loan Facility						Letter of Credit Facility				Bond Facility
	Non-Recourse Debt	Amount Outstanding as of June 30, 2014			Interest Rate		Maturity Date	Amount Outstanding as of June 30, 2014		Interest Rate	Maturity Date	Amount Outstanding as of June 30, 2014		Interest Rate	Maturity Date
	Broken Bow Wind	$	49		3-Month LIBOR + 2.875%		12/31/27	$	—	—	—	$	—	—	—
	Cedro Hill Wind	113			3-Month LIBOR + 3.125%		12/31/25	—		—	—	—		—	—
	Crofton Bluffs	25			3-Month LIBOR + 2.875%		12/31/27	—		—	—	—		—	—
	Laredo Ridge Wind	67			3-Month LIBOR + 2.875%		3/31/26	—		—	—	—		—	—
	Tapestry Wind	196			3-Month LIBOR + 2.500%		12/21/21	20		2.50%	12/21/21	—		—	—
	Viento Funding II	198			6-Month LIBOR + 2.750%		7/11/23	27		2.75%	7/11/20	—		—	—
	Walnut Creek Energy	409			3-Month LIBOR + 2.250%		5/31/23	60		2.00%	5/17/23	—		—	—
	WCEP Holding LLC	53			3-Month LIBOR + 4.000%		5/31/23	—		—	—	—		—	—
	American Bituminous	—			—		—	38		2.65%	11/7/14	36		0.06%/ Weekly per SIFMA rate(a)	10/1/17
	High Lonesome Mesa	—			—		—	—		—	—	62		6.85%	11/1/17
	Various	15			various		various	52		various	various	—		—	—
	Total	$	1,125					$	197			$	98
	(a) Securities Industry and Financial Markets Association, or SIFMA
Schedule of Swaps Related to Project Level Debt [Table Text Block]	'
	The following table summarizes the swaps related to EME's project level debt as of June 30, 2014.
	Non-Recourse Debt	% of Principal		Fixed Interest Rate			Floating Interest Rate	Notional Amount at June 30, 2014		Effective Date	Maturity Date
								(In millions)
	Walnut Creek Energy	90	%	3.543	%		3-Month LIBOR	$	368	28-Jun-13	31-May-23
	WCEP Holdings	90	%	4.003	%		3-Month LIBOR	48		28-Jun-13	31-May-23
	Viento Funding II	90	%	various			6-Month LIBOR	179		various	various
	Viento Funding II	90	%	4.985	%		6-Month LIBOR	63		July 11, 2023	June 30, 2028
	Cedro Hill	90	%	4.29	%		3-Month LIBOR	102		December 31, 2010	December 31, 2025
	Laredo Ridge	90	%	3.46	%		3-Month LIBOR	60		March 31, 2011	March 31, 2026
	Tapestry	90	%	2.21	%		3-Month LIBOR	176		December 30, 2011	December 21, 2021
	Tapestry	75	%	3.57	%		3-Month LIBOR	60		December 21, 2021	December 21, 2029
	Broken Bow	90	%	2.96	%		3-Month LIBOR	44		December 31, 2013	December 31, 2027
	Crofton Bluffs	90	%	2.748	%		3-Month LIBOR	23		December 31, 2013	December 31, 2027
	Total							$	1,123

Variable_Interest_Entities_Sum

Variable Interest Entities Summarized Financial Information (Tables)	6 Months Ended
	Jun. 30, 2014
Condensed Financial Statements	'
Additional Financial Information Disclosure [Text Block]	'
	The summarized financial information for Capistrano Wind Holdings consisted of the following:
	(In millions)	June 30, 2014
	Current assets	$	171
	Net property, plant and equipment	644
	Other long-term assets	6
	Total assets	821
	Current liabilities	29
	Long-term debt	188
	Other long-term liabilities	186
	Total liabilities	403
	Noncontrolling interests	$	388

Changes_in_Capital_Structure_T

Changes in Capital Structure (Tables)	6 Months Ended
	Jun. 30, 2014
Changes in Capital Structure Disclosure [Abstract]	'
Changes in NRG's common shares issued and outstanding	'
	The following table reflects the changes in NRG's common stock issued and outstanding:
		Issued		Treasury			Outstanding
	Balance as of December 31, 2013	401,126,780		(77,347,528	)		323,779,252
	Shares issued under LTIPs	950,546		—			950,546
	Shares issued under ESPP	—		71,595			71,595
	Shares issued in connection with the EME acquisition	12,671,977		—			12,671,977
	Balance as of June 30, 2014	414,749,303		(77,275,933	)		337,473,370
Schedule of dividends paid	'
	The following table lists the dividends paid during the six months ended June 30, 2014:
		Second Quarter 2014			First Quarter 2014
	Dividends per Common Share	$	0.14		$	0.12

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Reconciliation of NRG's basic and diluted earnings per share	'
	The reconciliation of NRG's basic and diluted (loss)/earnings per share is shown in the following table:
		Three months ended June 30,							Six months ended June 30,
	(In millions, except per share data)	2014				2013			2014			2013
	Basic (loss)/earnings per share attributable to NRG Energy, Inc. common stockholders
	Net (loss)/income attributable to NRG Energy, Inc.	$	(97	)		$	124		$	(153	)	$	(208	)
	Dividends for preferred shares	3				3			5			5
	(Loss)/earnings available for common stockholders	$	(100	)		$	121		$	(158	)	$	(213	)
	Weighted average number of common shares outstanding	337				323			331			323
	(Loss)/earnings per weighted average common share — basic	$	(0.30	)		$	0.37		$	(0.48	)	$	(0.66	)
	Diluted (loss)/earnings per share attributable to NRG Energy, Inc. common stockholders
	Weighted average number of common shares outstanding	337				323			331			323
	Incremental shares attributable to the issuance of equity compensation (treasury stock method)	—				4			—			—
	Total dilutive shares	337				327			331			323
	(Loss)/earnings per weighted average common share — diluted	$	(0.30	)		$	0.37		$	(0.48	)	$	(0.66	)
Summary of NRG's outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted earnings per share	'
	The following table summarizes NRG’s outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company’s diluted (loss)/earnings per share:
		Three months ended June 30,						Six months ended June 30,
	(In millions of shares)	2014			2013			2014		2013
	Equity compensation plans	8			2			8		11
	Embedded derivative of 3.625% redeemable perpetual preferred stock	16			16			16		16
	Total	24			18			24		27

Segment_Reporting_Tables

Segment Reporting (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting Disclosure [Abstract]	'
Schedule of segment reporting information, by segment	'
	(In millions)				Conventional Power Generation
	Three months ended June 30, 2014	Retail(a)			Gulf Coast(a)			East(a)			West(a)		Renewables(a)			NRG Yield(a)		Corporate(a)(b)			Elimination			Total
	Operating revenues	$	1,879		$	1,003		$	881		$	165	$	164		$	134	$	60		$	(665	)	$	3,621
	Depreciation and amortization	33			144			74			27		58			36		14			—			386
	Equity in earnings/(losses) of unconsolidated affiliates	—			1			1			10		(2		)	14		4			(14		)	14
	(Loss)/income before income taxes	(111		)	134			6			33		1			36		(290		)	(15		)	(206		)
	Net (loss)/income attributable to NRG Energy, Inc.	(112		)	134			6			33		(19		)	28		(166		)	(1		)	(97		)
	Total assets as of June 30, 2014	$	5,531		$	14,459		$	10,260		$	2,158	$	8,381		$	3,236	$	28,311		$	(34,707	)	$	37,629
	(a) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	2		$	698		$	(53	)	$	—	$	4		$	—	$	14
	(b) Includes loss on debt extinguishment of $40 million.
	(In millions)				Conventional Power Generation
	Three months ended June 30, 2013	Retail(c)			Gulf Coast(c)			East(c)			West(c)		Renewables(c)			NRG Yield(c)		Corporate(c)(d)			Elimination			Total
	Operating revenues	$	1,535		$	963		$	826		$	124	$	55		$	82	$	26		$	(682	)	$	2,929
	Depreciation and amortization	36			136			87			12		25			10		7			—			313
	Equity in earnings/(loss) of unconsolidated affiliates	—			1			—			1		(1		)	2		—			5			8
	(Loss)/income before income taxes	(82		)	180			133			36		(13		)	35		(219		)	(2		)	68
	Net (loss)/income attributable to NRG Energy, Inc.	$	(82	)	$	180		$	133		$	36	$	(22	)	$	35	$	(156	)	$	—		$	124
	(c) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	1		$	606		$	66		$	3	$	—		$	—	$	6
	(d) Includes loss on debt extinguishment of $21 million.
	(In millions)				Conventional Power Generation
	Six months ended June 30, 2014	Retail(e)			Gulf Coast(e)			East(e)			West(e)		Renewables(e)			NRG Yield(e)		Corporate(e)(f)			Elimination			Total
	Operating revenues	$	3,405		$	1,477		$	2,281		$	275	$	214		$	274	$	98		$	(917	)	$	7,107
	Depreciation and amortization	66			287			140			39		106			60		23			—			721
	Equity in earnings/(losses) of unconsolidated affiliates	—			1			—			14		(6		)	15		4			(7		)	21
	Income/(loss) before income taxes	180			(203		)	225			41		(64		)	65		(526		)	(22		)	(304		)
	Net income/(loss) attributable to NRG Energy, Inc.	$	179		$	(203	)	$	225		$	41	$	(67	)	$	50	$	(372	)	$	(6	)	$	(153	)
	(e) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	4		$	839		$	30		$	—	$	4		$	—	$	40
	(f) Includes loss on debt extinguishment of $81 million
	(In millions)				Conventional Power Generation
	Six months ended June 30, 2013	Retail(g)			Gulf Coast(g)			East(g)			West(g)		Renewables(g)			NRG Yield(g)		Corporate(g)(h)			Elimination			Total
	Operating revenues	$	2,766		$	1,243		$	1,421		$	213	$	89		$	135	$	57		$	(914	)	$	5,010
	Depreciation and amortization	68			273			173			25		48			20		13			—			620
	Equity in earnings of unconsolidated affiliates	—			2			—			2		1			6		—			—			11
	Income/(loss) before income taxes	287			(251		)	(25		)	32		(28		)	46		(470		)	(6		)	(415		)
	Net income/(loss) attributable to NRG Energy, Inc.	$	287		$	(251	)	$	(25	)	$	32	$	(38	)	$	46	$	(255	)	$	(4	)	$	(208	)
	(g) Operating revenues include inter-segment sales and net derivative gains and losses of:	$	2		$	837		$	58		$	3	$	—		$	—	$	14
	(h) Includes loss on debt extinguishment of $49 million

Income_Taxes_Tables

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Schedule of Effective Income Tax Rate Reconciliation	'
	The income tax provision consisted of the following:
		Three months ended June 30,						Six months ended June 30,
	(In millions except otherwise noted)	2014			2013			2014			2013
	(Loss)/income before income taxes	$	(206	)	$	68		$	(304	)	$	(415	)
	Income tax benefit	(126		)	(63		)	(157		)	(215		)
	Effective tax rate	61.2		%	(92.6		)%	51.6		%	51.8		%

Condensed_Consolidating_Financ1

Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2014
Condensed Consolidating Financial Information Disclosure [Abstract]	'
Condensed Consolidating Statements of Operations	'
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Three Months Ended June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Operating Revenues
	Total operating revenues	$	2,514		$	1,129		$	—		$	(22	)	$	3,621
	Operating Costs and Expenses
	Cost of operations	2,048			762			11			(4		)	2,817
	Depreciation and amortization	211			170			5			—			386
	Selling, general and administrative	106			82			80			—			268
	Acquisition-related transaction and integration costs	—			7			33			—			40
	Development activity expenses	—			7			14			—			21
	Total operating costs and expenses	2,365			1,028			143			(4		)	3,532
	Operating Income/(Loss)	149			101			(143		)	(18		)	89
	Other Income/(Expense)
	Equity in earnings of consolidated subsidiaries	52			—			65			(117		)	—
	Equity in earnings of unconsolidated affiliates	6			17			—			(9		)	14
	Other income/(loss), net	3			4			(2		)	—			5
	Loss on debt extinguishment	—			—			(40		)	—			(40		)
	Interest expense	(5		)	(120		)	(149		)	—			(274		)
	Total other income/(expense)	56			(99		)	(126		)	(126		)	(295		)
	Income/(Loss) Before Income Taxes	205			2			(269		)	(144		)	(206		)
	Income tax expense/(benefit)	47			4			(177		)	—			(126		)
	Net Income/(Loss)	158			(2		)	(92		)	(144		)	(80		)
	Less: Net income attributable to noncontrolling interest	—			39			5			(27		)	17
	Net Income/(Loss) attributable to	$	158		$	(41	)	$	(97	)	$	(117	)	$	(97	)
	NRG Energy, Inc.
	(a)	All significant intercompany transactions have been eliminated in consolidation.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Six Months Ended June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Operating Revenues
	Total operating revenues	$	4,793		$	2,380		$	—		$	(66	)	$	7,107
	Operating Costs and Expenses
	Cost of operations	3,841			1,736			7			(34		)	5,550
	Depreciation and amortization	409			304			8			—			721
	Selling, general and administrative	211			139			144			—			494
	Acquisition-related transaction and integration costs	—			8			44			—			52
	Development activity expenses	—			17			23			—			40
	Total operating costs and expenses	4,461			2,204			226			(34		)	6,857
	Gain on sale of assets	—			19			—			—			19
	Operating Income/(Loss)	332			195			(226		)	(32		)	269
	Other Income/(Expense)
	Equity in earnings/(loss) of consolidated subsidiaries	101			(6		)	180			(275		)	—
	Equity in earnings of unconsolidated affiliates	10			18			—			(7		)	21
	Other income, net	4			8			5			(1		)	16
	Loss on debt extinguishment	—			(9		)	(72		)	—			(81		)
	Interest expense	(11		)	(227		)	(292		)	1			(529		)
	Total other income/(expense)	104			(216		)	(179		)	(282		)	(573		)
	Income/(Loss) Before Income Taxes	436			(21		)	(405		)	(314		)	(304		)
	Income tax expense/(benefit)	110			(6		)	(261		)	—			(157		)
	Net Income/(Loss)	326			(15		)	(144		)	(314		)	(147		)
	Less: Net income attributable to noncontrolling interest	—			36			9			(39		)	6
	Net Income/(Loss) attributable to	$	326		$	(51	)	$	(153	)	$	(275	)	$	(153	)
	NRG Energy, Inc.
	(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Operating Revenues
Total operating revenues	$	2,171		$	850		$	—		$	(92	)	$	2,929
Operating Costs and Expenses
Cost of operations	1,647			492			—			(88		)	2,051
Depreciation and amortization	207			103			3			—			313
Selling, general and administrative	110			66			58			(4		)	230
Acquisition-related transaction and integration costs	—			12			15			—			27
Development activity expenses	—			7			14			—			21
Total operating costs and expenses	1,964			680			90			(92		)	2,642
Operating Income/(Loss)	207			170			(90		)	—			287
Other Income/(Expense)
Equity in earnings/(losses) of consolidated subsidiaries	20			(2		)	208			(226		)	—
Equity in earnings of unconsolidated affiliates	1			4			—			3			8
Other income, net	1			(2		)	1			—			—
Loss on debt extinguishment	—			(11		)	(10		)	—			(21		)
Interest expense	(5		)	(77		)	(124		)	—			(206		)
Total other income/(expense)	17			(88		)	75			(223		)	(219		)
Income/Loss Before Income Taxes	224			82			(15		)	(223		)	68
Income tax expense/(benefit)	65			11			(139		)	—			(63		)
Net Income	159			71			124			(223		)	131
Less: Net income attributable to noncontrolling interest	—			4			—			3			7
Net Income attributable to NRG Energy, Inc.	$	159		$	67		$	124		$	(226	)	$	124
(a)	All significant intercompany transactions have been eliminated in consolidation.
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Six Months Ended June 30, 2013
(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Operating Revenues
Total operating revenues	$	3,761		$	1,375		$	—		$	(126	)	$	5,010
Operating Costs and Expenses
Cost of operations	2,905			1,007			7			(115		)	3,804
Depreciation and amortization	411			203			6			—			620
Selling, general and administrative	225			118			125			(11		)	457
Acquisition-related transaction and integration costs	—			41			28			—			69
Development activity expenses	—			13			26			—			39
Total operating costs and expenses	3,541			1,382			192			(126		)	4,989
Operating Income/(Loss)	220			(7		)	(192		)	—			21
Other Income/(Expense)
Equity in earnings/(losses) of consolidated subsidiaries	21			(4		)	44			(61		)	—
Equity in earnings of unconsolidated affiliates	2			6			—			3			11
Other income, net	2			—			2			—			4
Loss on debt extinguishment	—			(11		)	(38		)	—			(49		)
Interest expense	(10		)	(141		)	(251		)	—			(402		)
Total other income/(expense)	15			(150		)	(243		)	(58		)	(436		)
Income/(Loss) Before Income Taxes	235			(157		)	(435		)	(58		)	(415		)
Income tax expense/(benefit)	86			(74		)	(227		)	—			(215		)
Net Income/(Loss)	149			(83		)	(208		)	(58		)	(200		)
Less: Net income attributable to noncontrolling interest	—			5			—			3			8
Net Income/(Loss) attributable to NRG Energy, Inc.	$	149		$	(88	)	$	(208	)	$	(61	)	$	(208	)
(a)	All significant intercompany transactions have been eliminated in consolidation.
Condensed Consolidating Statements of Comprehensive Income/(Loss)	'
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME/(LOSS)
	For the Three Months Ended June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Net Income/(Loss)	$	158		$	(2	)	$	(92	)	$	(144	)	$	(80	)
	Other comprehensive income, net of tax
	Unrealized gain/(loss) on derivatives, net	2			(20		)	(8		)	7			(19		)
	Foreign currency translation adjustments, net	—			(1		)	(2		)	—			(3		)
	Available-for-sale securities, net	—			5			4			(2		)	7
	Defined benefit plan, net	(2		)	(13		)	25			—			10
	Other comprehensive income/(loss)	—			(29		)	19			5			(5		)
	Comprehensive income/(loss)	158			(31		)	(73		)	(139		)	(85		)
	Less: Comprehensive income attributable to noncontrolling interest	—			32			5			(25		)	12
	Comprehensive income/(loss) attributable to NRG Energy, Inc.	158			(63		)	(78		)	(114		)	(97		)
	Dividends for preferred shares	—			—			3			—			3
	Comprehensive income/(loss) available for common stockholders	$	158		$	(63	)	$	(81	)	$	(114	)	$	(100	)
	(a)	All significant intercompany transactions have been eliminated in consolidation.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME/(LOSS)
	For the Six Months Ended June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Net Income/(Loss)	$	326		$	(15	)	$	(144	)	$	(314	)	$	(147	)
	Other comprehensive income, net of tax
	Unrealized gain/(loss) on derivatives, net	8			(26		)	(3		)	(7		)	(28		)
	Foreign currency translation adjustments, net	—			5			(2		)	—			3
	Available-for-sale securities, net	—			5			8			—			13
	Defined benefit plan, net	—			(13		)	25			—			12
	Other comprehensive income/(loss)	8			(29		)	28			(7		)	—
	Comprehensive income/(loss)	334			(44		)	(116		)	(321		)	(147		)
	Less: Comprehensive income/(loss) attributable to noncontrolling interest	—			27			9			(39		)	(3		)
	Comprehensive income/(loss) attributable to NRG Energy, Inc.	334			(71		)	(125		)	(282		)	(144		)
	Dividends for preferred shares	—			—			5			—			5
	Comprehensive income/(loss) available for common stockholders	$	334		$	(71	)	$	(130	)	$	(282	)	$	(149	)
	(a)	All significant intercompany transactions have been eliminated in consolidation.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME
	For the Three Months Ended June 30, 2013
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Net Income	$	159		$	71		$	124		$	(223	)	$	131
	Other comprehensive (loss)/income, net of tax
	Unrealized (loss)/gain on derivatives, net	(32		)	44			(15		)	20			17
	Foreign currency translation adjustments, net	—			(15		)	(4		)	—			(19		)
	Defined benefit plan	—			25			(5		)	—			20
	Other comprehensive (loss)/income	(32		)	54			(24		)	20			18
	Comprehensive income	127			125			100			(203		)	149
	Less: Comprehensive income attributable to noncontrolling interest	—			9			—			(2		)	7
	Comprehensive income attributable to NRG Energy, Inc.	127			116			100			(201		)	142
	Dividends for preferred shares	—			—			3			—			3
	Comprehensive income available for common stockholders	$	127		$	116		$	97		$	(201	)	$	139
	(a)	All significant intercompany transactions have been eliminated in consolidation.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME/(LOSS)
	For the Six Months Ended June 30, 2013
	(Unaudited)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
							(Note Issuer)
	(In millions)
Net Income/(Loss)	$	149		$	(83	)	$	(208	)	$	(58	)	$	(200	)
Other comprehensive (loss)/income, net of tax
Unrealized (loss)/gain on derivatives, net	(41		)	49			(8		)	24			24
Foreign currency translation adjustments, net	—			(15		)	(4		)	—			(19		)
Available-for-sale securities, net	—			—			2			—			2
Defined benefit plan	—			25			—			—			25
Other comprehensive (loss)/income	(41		)	59			(10		)	24			32
Comprehensive income/(loss)	108			(24		)	(218		)	(34		)	(168		)
Less: Comprehensive income attributable to noncontrolling interest	—			10			—			(2		)	8
Comprehensive income/(loss) attributable to NRG Energy, Inc.	108			(34		)	(218		)	(32		)	(176		)
Dividends for preferred shares	—			—			5			—			5
Comprehensive income/(loss) available for common stockholders	$	108		$	(34	)	$	(223	)	$	(32	)	$	(181	)
(a)	All significant intercompany transactions have been eliminated in consolidation.
Condensed Consolidating Balance Sheets	'
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING BALANCE SHEETS
	June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
	ASSETS	(In millions)
	Current Assets
	Cash and cash equivalents	$	25		$	1,121		$	335		$	—		$	1,481
	Funds deposited by counterparties	5			4			—			—			9
	Restricted cash	9			276			1			—			286
	Accounts receivable, net	1,205			277			—			—			1,482
	Inventory	419			577			—			—			996
	Derivative instruments	989			852			—			(140		)	1,701
	Deferred income taxes	—			41			38			—			79
	Cash collateral paid in support of energy risk management activities	282			290			—			—			572
	Accounts receivable - affiliate	5,661			821			(4,748		)	(1,724		)	10
	Renewable energy grant receivable	—			614			—			—			614
	Prepayments and other current assets	128			367			32			—			527
	Total current assets	8,723			5,240			(4,342		)	(1,864		)	7,757
	Net property, plant and equipment	8,884			12,563			153			(24		)	21,576
	Other Assets
	Investment in subsidiaries	573			(932		)	22,474			(22,115		)	—
	Equity investments in affiliates	(20		)	1,014			—			(129		)	865
	Notes receivable, less current portion	—			73			108			(96		)	85
	Goodwill	2,064			52						—			2,116
	Intangible assets, net	958			545			(47		)	(22		)	1,434
	Nuclear decommissioning trust fund	576			—			—			—			576
	Deferred income tax	8			586			906			—			1,500
	Derivative instruments	172			269			—			(28		)	413
	Other non-current assets	96			637			574						1,307
	Total other assets	4,427			2,244			24,015			(22,390		)	8,296
	Total Assets	$	22,034		$	20,047		$	19,826		$	(24,278	)	$	37,629
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current Liabilities
	Current portion of long-term debt and capital leases	$	1		$	813		$	19		$	—		$	833
	Accounts payable	748			325			30			—			1,103
	Accounts payable — affiliate	1,054			365			305			(1,724		)	—
	Derivative instruments	1,029			847			—			(140		)	1,736
	Cash collateral received in support of energy risk management activities	5			4			—			—			9
	Accrued expenses and other current liabilities	283			491			291						1,065
	Total current liabilities	3,120			2,845			645			(1,864		)	4,746
	Other Liabilities
	Long-term debt and capital leases	316			9,272			8,673			(96		)	18,165
	Nuclear decommissioning reserve	302			—			—			—			302
	Nuclear decommissioning trust liability	336			—			—			—			336
	Deferred income taxes	1,142			(1,003		)	(68		)	—			71
	Derivative instruments	189			194			—			(29		)	354
	Out-of-market contracts	119			1,056			—			—			1,175
	Other non-current liabilities	424			583			247						1,254
	Total non-current liabilities	2,828			10,102			8,852			(125		)	21,657
	Total liabilities	5,948			12,947			9,497			(1,989		)	26,403
	3.625% convertible perpetual preferred stock	—			—			249			—			249
	Stockholders’ Equity	16,086			7,100			10,080			(22,289		)	10,977
	Total Liabilities and Stockholders’ Equity	$	22,034		$	20,047		$	19,826		$	(24,278	)	$	37,629
	(a)	All significant intercompany transactions have been eliminated in consolidation.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING BALANCE SHEETS
	December 31, 2013
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
	ASSETS	(In millions)
	Current Assets
Cash and cash equivalents	$	56		$	870		$	1,328		$	—		$	2,254
Funds deposited by counterparties	7			56			—			—			63
Restricted cash	12			252			4			—			268
Accounts receivable, net	965			249			—			—			1,214
Inventory	436			462			—			—			898
Derivative instruments	866			470			—			(8		)	1,328
Deferred income taxes	—			41			217			—			258
Cash collateral paid in support of energy risk management activities	214			62			—			—			276
Renewable energy grant receivable	—			539			—			—			539
Prepayments and other current assets	4,778			379			(3,802		)	(857		)	498
Total current assets	7,334			3,380			(2,253		)	(865		)	7,596
Net Property, Plant and Equipment	9,116			10,604			153			(22		)	19,851
Other Assets
Investment in subsidiaries	32			422			18,266			(18,720		)	—
Equity investments in affiliates	(30		)	583			—			(100		)	453
Capital leases and notes receivable, less current portion	—			62			105			(94		)	73
Goodwill	1,973			12			—			—			1,985
Intangible assets, net	925			232			4			(21		)	1,140
Nuclear decommissioning trust fund	551			—			—			—			551
Deferred income taxes				681			521			—			1,202
Derivative instruments	110			202			—			(1		)	311
Other non-current assets	76			281			383			—			740
Total other assets	3,637			2,475			19,279			(18,936		)	6,455
Total Assets	$	20,087		$	16,459		$	17,179		$	(19,823	)	$	33,902
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Current portion of long-term debt and capital leases	$	1		$	1,029		$	20		$	—		$	1,050
Accounts payable	652			352			34			—			1,038
Accounts payable — affiliate	1,350			760			(1,253		)	(857		)	—
Derivative instruments	859			204			—			(8		)	1,055
Cash collateral received in support of energy risk management activities	6			57			—			—			63
Accrued expenses and other current liabilities	297			410			291			—			998
Total current liabilities	3,165			2,812			(908		)	(865		)	4,204
Other Liabilities
Long-term debt and capital leases	317			7,837			7,707			(94		)	15,767
Nuclear decommissioning reserve	294			—			—			—			294
Nuclear decommissioning trust liability	324			—			—			—			324
Deferred income taxes	1,024			(1,002		)	—			—			22
Derivative instruments	147			49			—			(1		)	195
Out-of-market contracts	127			1,050			—			—			1,177
Other non-current liabilities	412			615			174			—			1,201
Total non-current liabilities	2,645			8,549			7,881			(95		)	18,980
Total liabilities	5,810			11,361			6,973			(960		)	23,184
3.625% Preferred Stock	—			—			249			—			249
Stockholders’ Equity	14,277			5,098			9,957			(18,863		)	10,469
Total Liabilities and Stockholders’ Equity	$	20,087		$	16,459		$	17,179		$	(19,823	)	$	33,902
(a)	All significant intercompany transactions have been eliminated in consolidation.
Condensed Consolidating Statements of Cash Flows	'
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Six Months Ended June 30, 2014
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated
								(Note Issuer)
		(In millions)
	Cash Flows from Operating Activities
	Net Cash Provided/(Used) by Operating Activities	$	798		$	641		$	(2,429	)	$	1,360		$	370
	Cash Flows from Investing Activities
	(Payments for)/proceeds from intercompany loans to subsidiaries	(808		)	(552		)	1,360			—			—
	Acquisition of businesses, net of cash acquired	—			(25		)	(1,792		)	—			(1,817		)
	Capital expenditures	(9		)	(134		)	(364		)	—			(507		)
	(Increase)/decrease in restricted cash, net	(2		)	(5		)	1			—			(6		)
	Decrease/(increase) in restricted cash — U.S. DOE projects	—			24			(3		)	—			21
	Decrease in notes receivable	—			2			—			—			2
	Investments in nuclear decommissioning trust fund securities	(340		)	—			—			—			(340		)
	Proceeds from sales of nuclear decommissioning trust fund securities	334			—			—			—			334
	Proceeds from renewable energy grants	—			429			—			—			429
	Proceeds from sale of assets, net of cash disposed of	—			—			77			—			77
	Cash proceeds to fund cash grant bridge loan payment	—			57			—			—			57
	Other	(4		)	1			—			—			(3		)
	Net Cash Used by Investing Activities	(829		)	(203		)	(721		)	—			(1,753		)
	Cash Flows from Financing Activities
	Proceeds from/(payments for) intercompany loans	—			—			1,360			(1,360		)	—
	Payment of dividends to common and preferred stockholders	—			—			(91		)	—			(91		)
	Net payments for settlement of acquired derivatives that include financing elements	—			(167		)	—			—			(167		)
	Contributions from noncontrolling interest in subsidiaries	—			10			—			—			10
	Proceeds from issuance of long-term debt	—			551			3,335			—			3,886
	Proceeds from issuance of common stock	—			—			8			—			8
	Payment of debt issuance and hedging costs	—			(15		)	(28		)	—			(43		)
	Payments for short and long-term debt	—			(542		)	(2,427		)	—			(2,969		)
	Net Cash (Used)/Provided by Financing Activities	—			(163		)	2,157			(1,360		)	634
	Effect of exchange rate changes on cash and cash equivalents	—			(24		)	—			—			(24		)
	Net (Decrease)/Increase in Cash and Cash Equivalents	(31		)	251			(993		)	—			(773		)
	Cash and Cash Equivalents at Beginning of Period	56			870			1,328			—			2,254
	Cash and Cash Equivalents at End of Period	$	25		$	1,121		$	335		$	—		$	1,481
	(a)	All significant intercompany transactions have been eliminated in consolidation.
	NRG ENERGY, INC. AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Six Months Ended June 30, 2013
	(Unaudited)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Energy, Inc.			Eliminations(a)			Consolidated Balance
								(Note Issuer)
		(In millions)
	Cash Flows from Operating Activities
	Net Cash Provided/(Used) by Operating Activities	$	664		$	(288	)	$	(844	)	$	390		$	(78	)
	Cash Flows from Investing Activities
	Intercompany loans to subsidiaries	(393		)	3			390			—			—
	Acquisition of businesses, net of cash acquired	—			(39		)	—			—			(39		)
	Capital expenditures	(196		)	(1,081		)	(4		)	—			(1,281		)
	(Increase)/decrease in restricted cash, net	(2		)	(30		)	1			—			(31		)
	Increase in restricted cash — U.S. DOE projects	—			(10		)	(6		)	—			(16		)
	Decrease/(increase) in notes receivable	3			(6		)	(8		)	—			(11		)
	Investments in nuclear decommissioning trust fund securities	(233		)	—			—			—			(233		)
	Proceeds from sales of nuclear decommissioning trust fund securities	208			—			—			—			208
	Proceeds from renewable energy grants	—			48			—			—			48
	Other	(8		)	(12		)	—			—			(20		)
	Net Cash (Used)/Provided by Investing Activities	(621		)	(1,127		)	373			—			(1,375		)
	Cash Flows from Financing Activities
	Proceeds from intercompany loans	—			—			390			(390		)	—
	Payment of dividends to preferred stockholders	—			—			(73		)	—			(73		)
	Payment for treasury stock	—			—			(25		)	—			(25		)
Net (payment for)/receipts from settlement of acquired derivatives that include financing elements	(49		)	220			—			—			171
Proceeds from issuance of long-term debt	—			995			477			—			1,472
Proceeds from issuance of common stock	—			—			9			—			9
Sale proceeds and other contributions from noncontrolling interest in subsidiaries	—			33			—			—			33
Payment of debt issuance costs	—			(7		)	(28		)	—			(35		)
Payments for short and long-term debt	—			(607		)	(209		)	—			(816		)
Net Cash (Used)/Provided by Financing Activities	(49		)	634			541			(390		)	736
Effect of exchange rate changes on cash and cash equivalents	—			(2		)	—			—			(2		)
Net (Decrease)/Increase in Cash and Cash Equivalents	(6		)	(783		)	70			—			(719		)
Cash and Cash Equivalents at Beginning of Period	78			1,258			751			—			2,087
Cash and Cash Equivalents at End of Period	$	72		$	475		$	821		$	—		$	1,368
(a)	All significant intercompany transactions have been eliminated in consolidation.

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Noncontrolling Interest [Line Items]	'	'	'	'	'
Capital expenditures accrued and unpaid	'	'	$127	'	'
Stockholders' Equity Attributable to Noncontrolling Interest	1,160	'	1,160	'	867
Non-cash adjustment to non-controlling interest	'	'	-76	'	'
Noncontrolling Interest Increase From Contributions From Noncontrolling Interest Holders	'	'	25	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	'	'	-15	'	'
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	12	7	-3	8	'
Edison Mission Energy [Member]	'	'	'	'	'
Noncontrolling Interest [Line Items]	'	'	'	'	'
Noncontrolling Interest, Increase from Business Combination	'	'	380	'	'
NRG Yield, Inc.	'	'	'	'	'
Noncontrolling Interest [Line Items]	'	'	'	'	'
Sale of Assets Under Common Control	'	'	-41	'	'
Non-cash adjustment for issuance of convertible debt	'	'	$23	'	'

Basis_of_Presentation_Basis_of

Basis of Presentation Basis of Presentation (Details) (NRG Yield Inc.)	Jul. 22, 2013
NRG	'
Basis of Presentation	'
Common Stock, Voting Interest	65.50%
Public Shareholders	'
Basis of Presentation	'
Common Stock, Voting Interest	34.50%

Business_Acquisitions_and_Disp2

Business Acquisitions and Dispositions (Details) (USD $)

3 Months Ended

6 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Mar. 31, 2014

Apr. 02, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Apr. 30, 2014

Dec. 31, 2013

Aug. 07, 2013

Apr. 02, 2014

Apr. 02, 2014

Oct. 18, 2013

Apr. 02, 2014

Jun. 30, 2014

Oct. 19, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Aug. 05, 2014

Apr. 02, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jul. 07, 2014

Jul. 03, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jul. 30, 2014

Jun. 30, 2014

Petra Nova Parish Holdings [Member]

EME [Member]

Dominion [Member]

Edison Mission Energy [Member]

Edison Mission Energy [Member]

Edison Mission Energy [Member]

Edison Mission Energy [Member]

Edison Mission Energy [Member]

Sunrise Facility [Member]

Energy Systems Company [Member]

Gregory

Common Stock [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Scenario, Actual [Member]

Scenario, Plan [Member]

Scenario, Plan [Member]

Customer Relationships [Member]

Customer Relationships [Member]

Trade Names [Member]

Through 2034 [Member]

Subsequent Event [Member]

Subsequent Event [Member]

ROFO Assets [Member]

ROFO Assets [Member]

ROFO Assets [Member]

Petra Nova Parish Holdings [Member]

Petra Nova Parish Holdings [Member]

Petra Nova Parish Holdings [Member]

Department of Energy [Member]

JBIC and Mizuho [Member]

NEXI Covered Loan [Member]

JBIC [Member]

Common Class A [Member]

Coal, Gas and Transportation Commitments [Member]

MW

MW

MW

MW

Edison Mission Energy [Member]

Edison Mission Energy [Member]

Common Stock [Member]

Edison Mission Energy [Member]

Alta Wind Holdings [Member]

Edison Mission Energy [Member]

Dominion [Member]

Energy Systems Company [Member]

Dominion [Member]

NRG Yield [Member]

Edison Mission Energy [Member]

Base Purchase Price [Member]

Working Capital Adjustment [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

EME [Member]

Edison Mission Energy [Member]

MW

NRG Yield, Inc.

Business Acquisition

'

'

'

'

'

'

'

'

'

'

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'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of Ownership Sold of Subsidiary

'

'

'

'

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'

'

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'

'

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'

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50.00%

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Capital Contribution to Equity Method Investment

'

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$35,000,000

'

'

'

'

'

'

'

Proceeds from Divestiture of Interest in Subsidiaries and Affiliates

'

'

'

'

'

'

'

'

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'

'

'

'

'

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76,000,000

'

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'

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'

'

'

Amount guaranteed to borrow by US DOE

'

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167,000,000

'

'

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'

'

Long-term Debt

18,988,000,000

'

18,988,000,000

'

16,804,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

612,000,000

'

'

'

'

'

7,000,000

250,000,000

75,000,000

175,000,000

'

'

Interest rate, basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.75%

0.50%

'

'

Debt Instrument, Incremental Escalation On Basis Spread, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

'

'

Interest rate, stated rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

Consideration Paid for Sale of Assets Under Common Control

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

357,000,000

349,000,000

8,000,000

'

'

'

'

'

'

'

'

'

Capital Contributions From Partners in Equity Method Investment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

Business Acquisition, Pro Forma Revenue

'

'

'

5,618,000,000

'

'

'

'

'

'

7,655,000,000

'

12,598,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Pro Forma Net Income (Loss)

'

'

'

'

'

'

'

'

'

'

-136,000,000

-390,000,000

-1,009,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current and Non-Current Liabilities

'

'

'

'

'

'

'

'

533,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred

'

'

'

'

'

'

'

195,000,000

3,500,000,000

'

'

'

'

'

'

'

'

'

'

3,493,000,000

'

2,635,000,000

'

'

'

'

'

3,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Cash Acquired from Acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,422,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisitions, Consideration Transferred, Purchase Price

'

'

'

'

'

'

'

165,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Consideration Transferred, Working Capital

'

'

'

'

'

'

'

30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Generation Capacity (in MW)

'

'

'

'

'

0

'

'

8,000

'

'

'

'

586

'

388

'

'

'

'

947

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable Fair Value Method

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'401

[1]

'

'350

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Liabilities Incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

71,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition-related transaction and integration costs

40,000,000

27,000,000

52,000,000

69,000,000

'

'

'

'

'

14,000,000

17,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,671,977

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Estimated Consideration Transferred, Estimated Liabilities Incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

350,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents

'

'

'

'

'

'

'

'

1,422,000,000

'

'

'

'

'

'

32,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value

'

'

'

'

'

'

'

'

380,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Purchase Price Allocation, Noncurrent Liabilities, Long-term Debt

'

'

'

'

'

'

'

'

1,249,000,000

'

'

'

'

'

'

'

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Capital Lease Obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

485,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental Capital Expenditures, Estimated

906,000,000

'

906,000,000

'

'

'

439,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Businesses, Gross

'

'

'

'

'

'

'

'

'

'

'

'

'

'

120,000,000

'

'

'

'

3,021,000,000

[2]

870,000,000

2,285,000,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares, Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,075,000

'

Proceeds from Issuance or Sale of Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

630,000,000

'

Payments to Acquire Businesses, Net of Cash Acquired

'

'

1,817,000,000

39,000,000

'

'

'

'

'

'

'

'

'

'

'

245,000,000

'

'

'

2,071,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Finite-Lived Intangible Assets, Gross

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Steam Capacity (in MWt)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

160

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Purchase Price Allocation, Property, Plant and Equipment

'

'

'

'

'

'

'

'

2,475,000,000

'

'

'

'

'

60,000,000

248,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill

'

'

'

'

'

'

'

'

312,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total current assets

7,757,000,000

'

7,757,000,000

'

7,596,000,000

'

'

'

'

'

'

'

'

'

'

13,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

62,000,000

59,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other

'

'

'

'

'

'

'

10,000,000

676,000,000

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Derivative Assets

'

'

'

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Purchase Price Allocation, Liabilities Assumed

'

'

'

'

'

'

'

46,000,000

1,825,000,000

'

'

'

'

'

'

16,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill

2,116,000,000

'

2,116,000,000

'

1,985,000,000

'

'

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Out-of-market Contracts and Leases

'

'

'

'

'

'

'

'

43,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

'

'

'

'

'

'

'

'

3,493,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Pro Forma Earnings Per Share, Basic

'

'

'

'

'

'

'

'

'

'

$0

($1,000,000)

($3,002,976)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Pro Forma Earnings Per Share, Diluted

'

'

'

'

'

'

'

'

'

'

$0

($1,000,000)

($3,000,000)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Provisional Information, Initial Acquisition Accounting Adjustment, Derivative Assets

'

'

'

'

'

'

'

'

813,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets

'

'

'

'

'

'

'

'

5,698,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual

'

'

'

'

'

'

'

'

'

311,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual

'

'

'

'

'

'

'

'

'

14,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental Capital Expenditures, Estimated Total

'

'

'

'

'

'

350,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecorded Unconditional Purchase Obligation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$490,000,000

[1]

The increase in the value of the common shares reflects an increase in trading price of NRG common shares between October 18, 2013 and April 1, 2014. The shares of NRG common stock were given a value of $350 million in determining the cash purchase price, which was based upon the volume-weighted average trading price over the 20 trading days prior to October 18, 2013.

[2]

The increase in cash paid relates to an increase in acquired cash on hand as well as changes in cash collateral, restricted cash and cash related to unconsolidated subsidiaries. It also reflects lease and debt payments in 2014.

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions	'		'
Credit Derivative, Maximum Net Exposure, Percentage	100.00%	[1]	'
Long-term debt, including current portion	$18,988		$16,804
Carrying Amount	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions	'		'
Notes receivable	114	[2]	99	[2]
Long-term debt, including current portion	18,988		16,804
Fair Value	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions	'		'
Notes receivable	114	[2]	99	[2]
Long-term debt, including current portion	$19,576		$17,222
External Credit Rating, Non Investment Grade [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions	'		'
Credit Derivative, Maximum Net Exposure, Percentage	4.00%	[1]	'
[1]	Counterparty credit exposure excludes uranium and coal transportation contracts because of the unavailability of market prices.
[2]	Includes the current portion of notes receivable which is recorded in prepayments and other current assets on the Company's consolidated balance sheets

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments (Details 2) (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	$2,114		$1,639
Derivative liabilities	2,090		1,250
Commodity contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	2,106		1,619
Derivative liabilities	1,949		1,181
Interest rate contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	8		20
Derivative liabilities	141		69
Fair Value, Measurements, Recurring	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Available-for-sale Securities	14		2
Total liabilities	2,090		1,250
Fair Value | Fair Value, Measurements, Recurring	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Debt securities	18		16
Other	32	[1]	47	[1]
Total assets	2,755		2,256
Fair Value | Fair Value, Measurements, Recurring | Commodity contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	2,106		1,619
Derivative liabilities	1,949		1,181
Fair Value | Fair Value, Measurements, Recurring | Interest rate contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	8		20
Derivative liabilities	141		69
Fair Value | Fair Value, Measurements, Recurring | Cash and cash equivalents	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	3		26
Fair Value | Fair Value, Measurements, Recurring | U.S. government and federal agency obligations	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	41		45
Fair Value | Fair Value, Measurements, Recurring | Federal agency mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	62		62
Fair Value | Fair Value, Measurements, Recurring | Commercial mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	26		14
Fair Value | Fair Value, Measurements, Recurring | Corporate debt securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	92		70
Fair Value | Fair Value, Measurements, Recurring | Equity securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	350		332
Fair Value | Fair Value, Measurements, Recurring | Foreign government fixed income securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	2		2
Financial Instruments, Owned, US Government and Agency Obligations, at Fair Value	1		1
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Debt securities	18		16
Available-for-sale Securities	0		0
Other	11	[1]	10	[1]
Total assets	440		229
Total liabilities	365		134
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Commodity contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	353		147
Derivative liabilities	365		134
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Interest rate contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	0		0
Derivative liabilities	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Cash and cash equivalents	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | U.S. government and federal agency obligations	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Federal agency mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Commercial mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Corporate debt securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Equity securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	58		56
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring | Foreign government fixed income securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Financial Instruments, Owned, US Government and Agency Obligations, at Fair Value	0		0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Debt securities	0		0
Available-for-sale Securities	0		0
Other	0	[1]	0	[1]
Total assets	1,632		1,299
Total liabilities	1,490		900
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Commodity contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	1,438		1,126
Derivative liabilities	1,349		831
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Interest rate contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	8		20
Derivative liabilities	141		69
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Cash and cash equivalents	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | U.S. government and federal agency obligations	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	4		5
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Federal agency mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	62		62
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Commercial mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	26		14
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Corporate debt securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	92		70
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Equity securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring | Foreign government fixed income securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	2		2
Financial Instruments, Owned, US Government and Agency Obligations, at Fair Value	0		0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Debt securities	0		0
Available-for-sale Securities	14		2
Other	21	[1]	37	[1]
Total assets	683		728
Total liabilities	235		216
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Commodity contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	315		346
Derivative liabilities	235		216
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Interest rate contracts	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Derivative Assets	0		0
Derivative liabilities	0		0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Cash and cash equivalents	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	3		26
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | U.S. government and federal agency obligations	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	37		40
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Federal agency mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Commercial mortgage-backed securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Corporate debt securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Equity securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	292		276
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring | Foreign government fixed income securities	'		'
Fair Value Assets and Liabilities, Measured on Recurring Basis	'		'
Decommissioning Fund Investments	0		0
Financial Instruments, Owned, US Government and Agency Obligations, at Fair Value	$1		$1
[1]	Primarily consists of mutual funds held in rabbi trusts for non-qualified deferred compensation plans for certain former employees.

Fair_Value_of_Financial_Instru4

Fair Value of Financial Instruments (Details 3) (USD $)

3 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Fair Value Asset and Liabilities, Measured on Recurring Basis Unobservable Input, Changes

'

'

'

'

'

'

'

'

Valuation Allowances and Reserves, Balance

$1,000,000

'

$1,000,000

'

'

'

'

'

No transfers during the three and six months ended June 30, 2013 and 2013 (Level 1 to Level 2)

0

0

0

0

'

'

'

'

No transfers during the three and six months ended June 30, 2013 and 2013 (Level 2 to Level 1)

0

0

0

0

'

'

'

'

Fair Value, Inputs, Level 3 [Member]

'

'

'

'

'

'

'

'

Fair Value Asset and Liabilities, Measured on Recurring Basis Unobservable Input, Changes

'

'

'

'

'

'

'

'

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs

75,000,000

53,000,000

75,000,000

53,000,000

108,000,000

95,000,000

68,000,000

47,000,000

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings

-12,000,000

9,000,000

5,000,000

-18,000,000

'

'

'

'

Total gains/(losses) - realized/unrealized:

'

'

'

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases

-62,000,000

-5,000,000

-83,000,000

-6,000,000

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3

0

[1]

12,000,000

[1]

18,000,000

[1]

27,000,000

[1]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3

4,000,000

[1]

-32,000,000

[1]

-2,000,000

[1]

-2,000,000

[1]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)

0

2,000,000

2,000,000

3,000,000

'

'

'

'

Included in nuclear decom- missioning obligation

1,000,000

-1,000,000

1,000,000

2,000,000

'

'

'

'

Gains/(losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of period end

2,000,000

24,000,000

21,000,000

3,000,000

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Contracts Acquired

36,000,000

'

39,000,000

'

'

'

'

'

Fair Value, Inputs, Level 3 [Member] | Debt Securities

'

'

'

'

'

'

'

'

Fair Value Asset and Liabilities, Measured on Recurring Basis Unobservable Input, Changes

'

'

'

'

'

'

'

'

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs

18,000,000

15,000,000

18,000,000

15,000,000

18,000,000

16,000,000

13,000,000

12,000,000

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings

0

0

0

0

'

'

'

'

Total gains/(losses) - realized/unrealized:

'

'

'

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases

0

0

0

0

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3

0

[1]

0

[1]

0

[1]

0

[1]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3

0

[1]

0

[1]

0

[1]

0

[1]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)

0

2,000,000

2,000,000

3,000,000

'

'

'

'

Included in nuclear decom- missioning obligation

0

0

0

0

'

'

'

'

Gains/(losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of period end

0

0

0

0

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Contracts Acquired

0

'

0

'

'

'

'

'

Fair Value, Inputs, Level 3 [Member] | Other Financial Instrument [Member]

'

'

'

'

'

'

'

'

Fair Value Asset and Liabilities, Measured on Recurring Basis Unobservable Input, Changes

'

'

'

'

'

'

'

'

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs

11,000,000

'

11,000,000

'

11,000,000

10,000,000

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings

0

'

1,000,000

'

'

'

'

'

Total gains/(losses) - realized/unrealized:

'

'

'

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases

0

'

0

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3

0

[1]

'

0

[1]

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3

0

[1]

'

0

[1]

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)

0

'

0

'

'

'

'

'

Included in nuclear decom- missioning obligation

0

'

0

'

'

'

'

'

Gains/(losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of period end

0

'

0

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Contracts Acquired

0

'

0

'

'

'

'

'

Fair Value, Inputs, Level 3 [Member] | Trust Fund Investments

'

'

'

'

'

'

'

'

Fair Value Asset and Liabilities, Measured on Recurring Basis Unobservable Input, Changes

'

'

'

'

'

'

'

'

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs

58,000,000

50,000,000

58,000,000

50,000,000

56,000,000

56,000,000

50,000,000

47,000,000

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings

0

0

0

0

'

'

'

'

Total gains/(losses) - realized/unrealized:

'

'

'

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases

1,000,000

1,000,000

1,000,000

1,000,000

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3

0

[1]

0

[1]

0

[1]

0

[1]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3

0

[1]

0

[1]

0

[1]

0

[1]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)

0

0

0

0

'

'

'

'

Included in nuclear decom- missioning obligation

1,000,000

-1,000,000

1,000,000

2,000,000

'

'

'

'

Gains/(losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of period end

0

0

0

0

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Contracts Acquired

0

'

0

'

'

'

'

'

Fair Value, Inputs, Level 3 [Member] | Derivative [Member]

'

'

'

'

'

'

'

'

Fair Value Asset and Liabilities, Measured on Recurring Basis Unobservable Input, Changes

'

'

'

'

'

'

'

'

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs

-12,000,000

[2]

-12,000,000

[2]

-12,000,000

[2]

-12,000,000

[2]

23,000,000

[2]

13,000,000

[2]

5,000,000

[2]

-12,000,000

[2]

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings

-12,000,000

[2]

9,000,000

[2]

4,000,000

[2]

-18,000,000

[2]

'

'

'

'

Total gains/(losses) - realized/unrealized:

'

'

'

'

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases

-63,000,000

[2]

-6,000,000

[2]

-84,000,000

[2]

-7,000,000

[2]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3

0

[1],[2]

12,000,000

[1],[2]

18,000,000

[1],[2]

27,000,000

[1],[2]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3

4,000,000

[1],[2]

-32,000,000

[1],[2]

-2,000,000

[1],[2]

-2,000,000

[1],[2]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)

0

[2]

0

[2]

0

[2]

0

[2]

'

'

'

'

Included in nuclear decom- missioning obligation

0

[2]

0

[2]

0

[2]

0

[2]

'

'

'

'

Gains/(losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of period end

2,000,000

[2]

24,000,000

[2]

21,000,000

[2]

3,000,000

[2]

'

'

'

'

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Contracts Acquired

$36,000,000

[2]

'

$39,000,000

'

'

'

'

'

[1]

Transfers in/out of Level 3 are related to the availability of external broker quotes and are valued as of the end of the reporting period. All transfers in/out are with Level 2.

[2]

Consists of derivative assets and liabilities, net.

Fair_Value_of_Financial_Instru5

Fair Value of Financial Instruments (Details 4) (USD $)	6 Months Ended
	Jun. 30, 2014		Jun. 30, 2013
Concentration of Credit Risk	'		'
Total derivative assets valued with prices provied by models and other valuation techniques (as a percent)	17.00%		'
Total derivative liabilities valued with prices provied by models and other valuation techniques (as a percent)	17.00%		'
Valuation Allowances and Reserves, Balance	$1,000,000		'
Increase in fair value as a result of the credit reserve	'		1,000,000
Increase in fair value as a result of the credit reserve, portion recorded in OCI	'		-2,000,000
Increase in fair value as a result of the credit reserve, portion recorded in operating revenue and cost of operations	'		-3,000,000
Counterparty credit exposure to a portion of the Company's counterparties	742,000,000		'
Collateral held (cash and letters of credit) against counterparty credit exposure to a portion of the Company's counterparties	12,000,000		'
Net counterparty credit exposure to a portion of the Company's counterparties	740,000,000		'
Company's exposure before collateral is expected to roll off by the end of 2014 (as a percent)	85.00%		'
Net Exposure (as a percent)	100.00%	[1]	'
Counterparty credit risk exposure to certain counterparties, threshold (as a percent)	10.00%		'
Aggregate counterparty credit risk exposure for counterparties representing exposure above threshold percentage	149,000,000		'
Estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements for the next 5 years	3,500,000,000		'
Period of estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements (in years)	'5 years		'
Investment grade	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	90.00%	[1]	'
Non-rated	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	6.00%	[1],[2]	'
External Credit Rating, Non Investment Grade [Member]	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	4.00%	[1]	'
Financial institutions	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	34.00%	[1]	'
Utilities, energy merchants, marketers and other	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	31.00%	[1]	'
ISOs	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	30.00%	[1]	'
Coal and emissions	'		'
Concentration of Credit Risk	'		'
Net Exposure (as a percent)	5.00%	[1]	'
NRG Yield, Inc.	'		'
Concentration of Credit Risk	'		'
Estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements for the next 5 years	$1,100,000,000		'
[1]	Counterparty credit exposure excludes uranium and coal transportation contracts because of the unavailability of market prices.
[2]	For non-rated counterparties, a significant portion are related to ISO and municipal public power entities, which are considered investment grade equivalent ratings based on NRG's internal credit ratings.

Nuclear_Decommissioning_Trust_2

Nuclear Decommissioning Trust Fund (Details) (USD $)	6 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	$576	'	$551
Unrealized Gains	225	'	207
Unrealized Losses	1	'	3
Realized gains	7	3	'
Available-for-sale Securities, Gross Realized Losses	3	4	'
Proceeds from Sale of Available-for-sale Securities	334	208	'
Cash and Cash Equivalents [Member]	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	3	'	26
Unrealized Gains	0	'	0
Unrealized Losses	0	'	0
Weighted-average Maturities (In years)	0	'	0
U.S. government and federal agency obligations	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	41	'	45
Unrealized Gains	2	'	1
Unrealized Losses	0	'	1
Weighted-average Maturities (In years)	9	'	9
Federal agency mortgage-backed securities	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	62	'	62
Unrealized Gains	1	'	1
Unrealized Losses	1	'	1
Weighted-average Maturities (In years)	25	'	24
Commercial mortgage-backed securities	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	26	'	14
Unrealized Gains	0	'	0
Unrealized Losses	0	'	0
Weighted-average Maturities (In years)	30	'	29
Corporate debt securities	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	92	'	70
Unrealized Gains	3	'	1
Unrealized Losses	0	'	1
Weighted-average Maturities (In years)	11	'	9
Equity securities	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	350	'	332
Unrealized Gains	219	'	204
Unrealized Losses	0	'	0
Weighted-average Maturities (In years)	0	'	0
Foreign government fixed income securities	'	'	'
Nuclear decommissioning trust fund disclosure	'	'	'
Fair Value	2	'	2
Unrealized Gains	0	'	0
Unrealized Losses	$0	'	$0
Weighted-average Maturities (In years)	16	'	9

Accounting_for_Derivative_Inst2

Accounting for Derivative Instruments and Hedging Activities (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

In Millions, unless otherwise specified

Derivatives Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Interest rate contracts

Interest rate contracts

Interest rate contracts current

Interest rate contracts current

Interest rate contracts current

Interest rate contracts current

Interest rate contracts long-term

Interest rate contracts long-term

Interest rate contracts long-term

Interest rate contracts long-term

Commodity contracts current

Commodity contracts current

Commodity contracts current

Commodity contracts current

Commodity contracts long-term

Commodity contracts long-term

Commodity contracts long-term

Commodity contracts long-term

Short Ton

Short Ton

Short Ton

Short Ton

MMbtu

MMbtu

Barrel

Barrel

MWh

MWh

Dollars

Dollars

CVSR

CVSR

CVSR

CVSR

Alpine

Alpine

Alpine

Alpine

Derivatives Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Derivatives Not Designated as Cash Flow Hedges

Emissions

Emissions

Coal

Coal

Natural Gas

Natural Gas

Oil

Oil

Power

Power

Interest

Interest

Interest rate contracts

Interest rate contracts

Interest rate contracts

Interest rate contracts

Interest rate contracts

Interest rate contracts

Interest rate contracts

Interest rate contracts

T

T

T

T

bbl

bbl

Derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss previously deferred in OCI recognized in earnings resulting from discontinued cash flow hedge accounting

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

$5

$0

$5

$0

$0

'

$0

Volumetric Underlying Derivative Transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount, Volume

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount, Energy Measure

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

239,000,000

-166,000,000

'

'

43,000,000

-27,000,000

'

'

'

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount, Mass

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

0

70,000,000

51,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Notional Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,569

1,444

'

'

'

'

'

'

'

'

Fair Value of Derivative Instrument

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Assets

2,114

1,639

7

14

2,107

1,625

8

20

0

0

0

0

7

14

1

6

0

0

1,701

1,328

0

0

405

291

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Liabilities

$2,090

$1,250

$133

$66

$1,957

$1,184

$141

$69

$59

$35

$5

$4

$74

$29

$3

$1

$0

$1

$1,672

$1,015

$0

$1

$277

$164

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounting_for_Derivative_Inst3

Accounting for Derivative Instruments and Hedging Activities (Details 2) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid	'	'	'	'	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	($12)	$31	($20)	$43	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	-51	-7	-51	-7	-32	-23	-24	-31
Gross Amount of Recognized Derivative Assets	2,114	'	2,114	'	'	1,639	'	'
Cash Collateral (Held)	-9	'	-9	'	'	-63	'	'
Gross Amounts of Recognized Derivative Liabilities	-2,090	'	-2,090	'	'	-1,250	'	'
Cash Collateral Posted	572	'	572	'	'	276	'	'
Gross Amounts of Recognized Assets / Liabilities	24	'	24	'	'	389	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-7	-14	-8	-19	'	'	'	'
Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset	0	'	0	'	'	0	'	'
Derivative, Collateral, Obligation to Return Cash Net Of Derivative, Collateral, Right to Reclaim Cash	71	'	71	'	'	-44	'	'
Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral	95	'	95	'	'	345	'	'
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	-13	17	-13	17	'	'	'	'
Commodity contracts	'	'	'	'	'	'	'	'
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid	'	'	'	'	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	0	-3	0	6	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	-1	24	-1	24	-1	-1	42	41
Gross Amount of Recognized Derivative Assets	2,106	'	2,106	'	'	1,619	'	'
Derivative Instruments	-1,706	'	-1,706	'	'	-1,032	'	'
Cash Collateral (Held)	-4	'	-4	'	'	-62	'	'
Net Amount	396	'	396	'	'	525	'	'
Gross Amounts of Recognized Derivative Liabilities	-1,949	'	-1,949	'	'	-1,181	'	'
Derivative Instruments	1,706	'	1,706	'	'	1,032	'	'
Cash Collateral Posted	75	'	75	'	'	18	'	'
Derivative Liability, Fair Value, Amount Offset Against Collateral	168	'	168	'	'	131	'	'
Gross Amounts of Recognized Assets / Liabilities	157	'	157	'	'	438	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	-15	0	-23	'	'	'	'
Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset	0	'	0	'	'	0	'	'
Derivative, Collateral, Obligation to Return Cash Net Of Derivative, Collateral, Right to Reclaim Cash	71	'	71	'	'	-44	'	'
Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral	228	'	228	'	'	394	'	'
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	-1	26	-1	26	'	'	'	'
Interest rate contracts	'	'	'	'	'	'	'	'
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid	'	'	'	'	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	-12	34	-20	37	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	-50	-31	-50	-31	-31	-22	-66	-72
Gross Amount of Recognized Derivative Assets	8	'	8	'	'	20	'	'
Derivative Instruments	-6	'	-6	'	'	-12	'	'
Cash Collateral (Held)	0	'	0	'	'	0	'	'
Net Amount	2	'	2	'	'	8	'	'
Gross Amounts of Recognized Derivative Liabilities	-141	'	-141	'	'	-69	'	'
Derivative Instruments	6	'	6	'	'	12	'	'
Cash Collateral Posted	0	'	0	'	'	0	'	'
Derivative Liability, Fair Value, Amount Offset Against Collateral	135	'	135	'	'	57	'	'
Gross Amounts of Recognized Assets / Liabilities	-133	'	-133	'	'	-49	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-7	1	-8	4	'	'	'	'
Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset	0	'	0	'	'	0	'	'
Derivative, Collateral, Obligation to Return Cash Net Of Derivative, Collateral, Right to Reclaim Cash	0	'	0	'	'	0	'	'
Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral	-133	'	-133	'	'	-49	'	'
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	($12)	($9)	($12)	($9)	'	'	'	'

Accounting_for_Derivative_Inst4

Accounting for Derivative Instruments and Hedging Activities (Details 3) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Derivative	'	'	'	'	'
Derivative liabilities	$2,090	'	$2,090	'	$1,250
Gross Amount of Recognized Derivative Assets	2,114	'	2,114	'	1,639
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-7	-14	-8	-19	'
Effects of ASC 815 on NRG's Accumulated OCI Balance Attributable to Cash Flow Hedge Derivatives, net of tax	'	'	'	'	'
Accumulated OCI beginning balance	-32	-24	-23	-31	'
Mark-to-market of cash flow hedge accounting contracts	-12	31	-20	43	'
Accumulated OCI ending balance, net of tax	-51	-7	-51	-7	'
Gains/(losses) expected to be realized from OCI during the next 12 months, net of tax	-13	17	-13	17	'
Gains/(losses) recognized in income from the ineffective portion of cash flow hedges	'	-1	'	-1	'
Accumulated OCI ending balance, tax	29	4	29	4	'
Gains/(losses) expected to be realized from OCI during the next 12 months, tax	7	10	7	10	'
Unrealized mark-to-market results	'	'	'	'	'
Reversal of previously recognized unrealized losses/(gains) on settled positions related to economic hedges	-5	-7	-2	-32	'
Reversal of loss positions acquired as part of the acquisition	-84	-99	-162	-187	'
Net unrealized gains/(losses) on open positions related to economic hedges	-30	204	-223	55	'
Losses on ineffectiveness associated with open positions treated as cash flow hedges	0	0	0	-1	'
Total unrealized mark-to-market gains/(losses) for economic hedging activities	-119	98	-387	-165	'
Reversal of previously recognized unrealized (gains) losses on settled positions related to trading activity	5	-1	5	-29	'
Reversal of Previously Unrecognized Unrealized Gain Loss Acquired as Part of Acquisition Trading Activity	-19	2	-20	0	'
Net unrealized gains on open positions related to trading activity	14	-13	30	-26	'
Total unrealized mark-to-market gains for trading activity	0	-12	15	-55	'
Impact of derivative instruments on statement of operations	'	'	'	'	'
Total unrealized gains/(losses)	-119	86	-372	-220	'
Discontinuation of cash flow hedges	'	'	'	'	'
Derivative Liability, Fair Value of Collateral	71	'	71	'	'
Credit Risk Related Contingent Features	'	'	'	'	'
Collateral due on net liability position that has not been called by a certain marginable agreement counterparty	22	'	22	'	'
Commodity contracts	'	'	'	'	'
Derivative	'	'	'	'	'
Derivative liabilities	1,949	'	1,949	'	1,181
Gross Amount of Recognized Derivative Assets	2,106	'	2,106	'	1,619
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	-15	0	-23	'
Effects of ASC 815 on NRG's Accumulated OCI Balance Attributable to Cash Flow Hedge Derivatives, net of tax	'	'	'	'	'
Accumulated OCI beginning balance	-1	42	-1	41	'
Mark-to-market of cash flow hedge accounting contracts	0	-3	0	6	'
Accumulated OCI ending balance, net of tax	-1	24	-1	24	'
Gains/(losses) expected to be realized from OCI during the next 12 months, net of tax	-1	26	-1	26	'
Gains/(losses) recognized in income from the ineffective portion of cash flow hedges	'	0	'	-1	'
Impact of derivative instruments on statement of operations	'	'	'	'	'
Total unrealized gains/(losses)	-119	86	-372	-220	'
Commodity contracts | Sales [Member]	'	'	'	'	'
Impact of derivative instruments on statement of operations	'	'	'	'	'
Total unrealized gains/(losses)	-48	181	-364	-340	'
Commodity contracts | Gains (losses) included in cost of operations	'	'	'	'	'
Impact of derivative instruments on statement of operations	'	'	'	'	'
Total unrealized gains/(losses)	-71	-95	-8	120	'
Interest rate contracts	'	'	'	'	'
Derivative	'	'	'	'	'
Derivative liabilities	141	'	141	'	69
Gross Amount of Recognized Derivative Assets	8	'	8	'	20
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-7	1	-8	4	'
Effects of ASC 815 on NRG's Accumulated OCI Balance Attributable to Cash Flow Hedge Derivatives, net of tax	'	'	'	'	'
Accumulated OCI beginning balance	-31	-66	-22	-72	'
Mark-to-market of cash flow hedge accounting contracts	-12	34	-20	37	'
Accumulated OCI ending balance, net of tax	-50	-31	-50	-31	'
Gains/(losses) expected to be realized from OCI during the next 12 months, net of tax	-12	-9	-12	-9	'
Gains/(losses) recognized in income from the ineffective portion of cash flow hedges	'	-1	'	0	'
Impact of derivative instruments on statement of operations	'	'	'	'	'
Total unrealized gains/(losses)	-3	4	-7	6	'
Interest rate contracts | CVSR	'	'	'	'	'
Discontinuation of cash flow hedges	'	'	'	'	'
Loss previously deferred in OCI recognized in earnings resulting from discontinued cash flow hedge accounting	0	5	0	5	'
Interest rate contracts | Alpine	'	'	'	'	'
Discontinuation of cash flow hedges	'	'	'	'	'
Loss previously deferred in OCI recognized in earnings resulting from discontinued cash flow hedge accounting	$0	$0	'	$0	'

Debt_and_Capital_Leases_Detail

Debt and Capital Leases (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

2 Months Ended

2 Months Ended

0 Months Ended

2 Months Ended

1 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

Jun. 30, 2014

Mar. 31, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jan. 27, 2014

Jun. 30, 2014

Dec. 31, 2013

Jan. 27, 2013

Jan. 27, 2014

Jun. 30, 2014

Dec. 31, 2013

Jan. 27, 2013

Mar. 31, 2013

Feb. 27, 2013

Feb. 27, 2013

Jun. 30, 2014

Dec. 31, 2013

Feb. 27, 2013

Aug. 04, 2014

21-May-14

Apr. 21, 2014

Feb. 10, 2014

Jun. 30, 2014

Dec. 31, 2013

Feb. 27, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Apr. 21, 2014

Feb. 10, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2013

Jun. 04, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 04, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Feb. 21, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Mar. 31, 2013

Mar. 31, 2013

Mar. 31, 2013

Mar. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Mar. 31, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Apr. 25, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Aug. 05, 2014

Aug. 05, 2014

Jan. 27, 2014

Jan. 27, 2014

Jan. 27, 2014

Jan. 27, 2014

Recourse Debt

Recourse Debt

Recourse Debt

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Senior Notes 2024 [Member]

Senior Notes 2024 [Member]

Senior Notes 2024 [Member]

Senior Notes 2024 [Member]

Senior Notes Due In 2022 [Member]

Senior Notes Due In 2022 [Member]

Senior Notes Due In 2022 [Member]

Senior Notes Due In 2022 [Member]

Senior Notes Repurchases

Senior Notes Repurchases

Senior notes, due 2018

Senior notes, due 2018

Senior notes, due 2018

8.500% Senior notes, due 2019

8.500% Senior notes, due 2019

8.500% Senior notes, due 2019

8.500% Senior notes, due 2019

8.500% Senior notes, due 2019

8.500% Senior notes, due 2019

8.500% Senior notes, due 2019

Senior notes, due 2020

Senior notes, due 2020

Senior notes, due 2020

GenOn Senior Notes Due in 2014 [Member]

GenOn Senior Notes Due in 2014 [Member]

GenOn Senior Notes Due in 2017 [Member]

GenOn Senior Notes Due in 2017 [Member]

7.625% Senior notes, due 2019

7.625% Senior notes, due 2019

7.625% Senior notes, due 2019

7.625% Senior notes, due 2019

Senior notes, due 2021

Senior notes, due 2021

Senior notes, due 2023

Senior notes, due 2023

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Term loan facility, due 2018

Indian River Power LLC, tax-exempt bonds, due 2040 and 2045

Indian River Power LLC, tax-exempt bonds, due 2040 and 2045

Indian River Power LLC, tax-exempt bonds, due 2040

Indian River Power LLC, tax-exempt bonds, due 2045

Dunkirk Power LLC, tax-exempt bonds, due 2042

Dunkirk Power LLC, tax-exempt bonds, due 2042

Fort Bend County, tax-exempt bonds, due 2038 and 2042

Fort Bend County, tax-exempt bonds, due 2038 and 2042

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2021 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

GenOn senior notes, due 2018

GenOn senior notes, due 2018

GenOn senior notes, due 2020

GenOn senior notes, due 2020

GenOn Americas Generation senior notes, due in 2021

GenOn Americas Generation senior notes, due in 2021

GenOn Americas Generation senior notes, due in 2031

GenOn Americas Generation senior notes, due in 2031

Marsh Landing Term Loan Due 2017 [Member]

Marsh Landing Term Loan Due 2017 [Member]

Genon [Member]

Genon [Member]

GenOn Marsh Landing term loans, due 2017 and 2023

GenOn Marsh Landing term loans, due 2017 and 2023

GenOn Marsh Landing term loan, due 2023

GenOn Marsh Landing term loan, due 2023

CVSR - High Plains Ranch II LLC, due 2037

CVSR - High Plains Ranch II LLC, due 2037

NRG West Holdings LLC, term loan, due 2023

NRG West Holdings LLC, term loan, due 2023

NRG West Holdings LLC, term loan, due 2023

Agua Caliente Solar LLC, due 2037

Agua Caliente Solar LLC, due 2037

Ivanpah Financing, due 2014 and 2038

Ivanpah Financing, due 2014 and 2038

NRG Peaker Finance Co. LLC, bonds, due 2019

NRG Peaker Finance Co. LLC, bonds, due 2019

NRG Peaker Finance Co. LLC, bonds, due 2019

NRG Peaker Finance Co. LLC, bonds, due 2019

NRG Yield, Inc.

NRG Yield, Inc.

NRG Energy Center Minneapolis LLC, senior secured notes, due 2013, 2017, and 2025

NRG Energy Center Minneapolis LLC, senior secured notes, due 2013, 2017, and 2025

NRG Energy Center Minneapolis LLC Senior Secured Notes, due 2017

NRG Energy Center Minneapolis LLC Senior Secured Notes, due 2025

NRG Solar Alpine LLC, due 2022

NRG Solar Alpine LLC, due 2022

NRG Solar Alpine LLC, due 2022

NRG Solar Borrego LLC, due 2024 and 2038

NRG Solar Borrego LLC, due 2024 and 2038

Borrego Financing Agreement, due 2024

Borrego Financing Agreement, due 2024

Borrego Financing Agreement, due 2038

High Desert Facility

High Desert Facility

High Desert Facility

High Desert Facility

Kansas South Facility

Other (Non-recourse debt)

Other (Non-recourse debt)

NRG Energy [Member]

NRG Energy [Member]

Chalk Point capital lease, due 2015

Chalk Point capital lease, due 2015

Other (Capital leases)

Other (Capital leases)

Convertible Debt [Member]

NRG Yield - Other [Member]

NRG Yield - Other [Member]

NRG Yield Revolving Credit Facility [Member]

NRG Yield Revolving Credit Facility [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

EME [Member]

NRG Yield Inc.

NRG Yield Inc.

90 days following registration default [Member]

90 days following registration default [Member]

Maximum [Member]

Maximum [Member]

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Term Loan Facility [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Recourse Debt

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Revolving Credit Facility

Revolving Credit Facility

Bridge Loan

Bridge Loan

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Broken Bow Wind [Member]

Broken Bow Wind [Member]

Broken Bow Wind [Member]

Broken Bow Wind [Member]

Broken Bow Wind [Member]

High Lonesome Mesa, LLC, due in 2017 [Member]

High Lonesome Mesa, LLC, due in 2017 [Member]

High Lonesome Mesa, LLC, due in 2017 [Member]

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2021 [Member]

Tapestry Wind LLC due in 2029 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

Walnut Creek Energy, LLC, due in 2023 [Member]

WCEP Holdings, LLC, due in 2023 [Member]

WCEP Holdings, LLC, due in 2023 [Member]

WCEP Holdings, LLC, due in 2023 [Member]

WCEP Holdings, LLC, due in 2023 [Member]

WCEP Holdings, LLC, due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2023 [Member]

Viento Funding II, Inc., due in 2028 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Cedro Hill Wind LLC, due in 2025 [Member]

Crofton Bluffs [Member]

Crofton Bluffs [Member]

Crofton Bluffs [Member]

Crofton Bluffs [Member]

Crofton Bluffs [Member]

Laredo Ridge Wind, LLC, due in 2026 [Member]

Laredo Ridge Wind, LLC, due in 2026 [Member]

Laredo Ridge Wind, LLC, due in 2026 [Member]

Laredo Ridge Wind, LLC, due in 2026 [Member]

Laredo Ridge Wind, LLC, due in 2026 [Member]

Other (Non-recourse debt)

Other (Non-recourse debt)

Other (Non-recourse debt)

American Bituminous [Member]

American Bituminous [Member]

American Bituminous [Member]

5.375% Senior Notes due in 2024 [Member]

5.375% Senior Notes due in 2024 [Member]

Senior Notes 2024 [Member]

Senior Notes Due In 2022 [Member]

90 days following registration default [Member]

90 days following registration default [Member]

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Interest Rate Swap [Member]

Term Loan Facility [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Term Loan Facility [Member]

Letter of Credit [Member]

Bonds [Member]

Non Recourse Debt [Member]

Non Recourse Debt [Member]

Recourse Debt

Recourse Debt

Senior Notes 2024 [Member]

Senior Notes Due In 2022 [Member]

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

Recourse Debt

Recourse Debt

Debt and Capital Leases

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Percentage of Debt Hedged by Interest Rate Derivatives

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90.00%

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'

'

90.00%

'

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'

'

75.00%

90.00%

'

'

'

'

'

'

'

'

90.00%

90.00%

'

'

'

'

90.00%

90.00%

'

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'

'

90.00%

'

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'

'

90.00%

'

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Derivative, Fixed Interest Rate

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2.96%

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2.21%

'

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'

'

3.57%

3.54%

'

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'

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'

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4.00%

'

'

'

'

'

4.99%

4.29%

'

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'

'

2.75%

'

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'

'

3.46%

'

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'

'

'

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'

Long-term Debt

$18,988,000,000

'

'

$18,988,000,000

'

$16,804,000,000

$8,999,000,000

'

$8,087,000,000

$9,989,000,000

$8,717,000,000

'

$1,000,000,000

$0

'

'

$1,100,000,000

$0

'

'

'

'

$1,130,000,000

$1,130,000,000

'

'

'

'

'

$223,000,000

$602,000,000

'

$1,063,000,000

$1,062,000,000

'

'

$774,000,000

$782,000,000

'

'

$0

$800,000,000

$1,128,000,000

$1,128,000,000

$990,000,000

$990,000,000

$1,992,000,000

$2,002,000,000

'

'

'

'

'

'

'

$247,000,000

$247,000,000

'

'

$59,000,000

$59,000,000

$67,000,000

$67,000,000

$196,000,000

$0

'

$409,000,000

$0

'

$198,000,000

$0

'

$113,000,000

$0

'

$769,000,000

$780,000,000

$616,000,000

$621,000,000

$499,000,000

$503,000,000

$434,000,000

$435,000,000

'

'

$3,092,000,000

$3,121,000,000

$464,000,000

$473,000,000

'

'

$798,000,000

$1,104,000,000

$520,000,000

$512,000,000

'

$923,000,000

$878,000,000

$1,595,000,000

$1,575,000,000

'

$128,000,000

$154,000,000

'

$1,999,000,000

$1,783,000,000

$124,000,000

$127,000,000

'

'

$170,000,000

$221,000,000

'

$77,000,000

$78,000,000

'

'

'

'

'

'

'

'

$538,000,000

$102,000,000

$4,898,000,000

$3,813,000,000

'

'

'

'

'

$320,000,000

$372,000,000

'

'

'

$1,125,000,000

$197,000,000

$98,000,000

'

$49,000,000

'

$0

$0

$0

$0

$62,000,000

'

$196,000,000

'

$20,000,000

$0

'

'

$409,000,000

'

$60,000,000

$0

$53,000,000

'

$0

$0

'

'

$198,000,000

'

$27,000,000

$0

'

'

$113,000,000

'

$0

$0

'

$25,000,000

'

$0

$0

'

$67,000,000

'

$0

$0

$15,000,000

$52,000,000

$0

$0

$38,000,000

$36,000,000

'

'

'

'

'

'

Proceeds from Issuance of Senior Long-term Debt

'

'

'

'

'

'

'

'

'

'

'

1,000,000,000

'

'

'

1,100,000,000

'

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'

500,000,000

'

'

'

'

'

Long-term debt

'

'

'

'

'

'

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'

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'

'

'

'

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'

'

'

'

'

'

'

'

'

225,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Maturity Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Dec-27

'

'

'

'

'

1-Nov-17

'

21-Dec-21

'

21-Dec-21

'

'

'

31-May-23

'

17-May-23

'

31-May-23

'

'

'

'

'

11-Jul-23

'

11-Jul-20

'

'

'

31-Dec-25

'

'

'

'

31-Dec-27

'

'

'

'

31-Mar-26

'

'

'

'

'

'

'

7-Nov-14

1-Oct-17

'

'

'

'

'

'

Convertible Debt, Fair Value Disclosures

324,000,000

'

'

324,000,000

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Chalk Point capital lease, due 2015

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,000,000

10,000,000

3,000,000

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Subtotal

18,998,000,000

'

'

18,998,000,000

'

16,817,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Less current maturities

833,000,000

'

'

833,000,000

'

1,050,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt and capital leases

18,165,000,000

'

'

18,165,000,000

'

15,767,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, stated rate

'

'

'

'

'

'

'

'

'

'

'

'

6.25%

[1]

'

6.25%

'

6.25%

[1]

'

6.25%

'

'

'

7.63%

[1]

'

'

'

'

'

'

8.50%

[1]

8.50%

'

8.25%

[1]

'

'

'

7.88%

[1]

'

'

'

7.63%

[1]

7.63%

7.88%

[1]

'

6.63%

[1]

'

'

'

'

'

'

'

'

'

2.25%

[1]

'

'

6.00%

[1]

5.38%

[1]

5.88%

[1]

'

4.75%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

9.50%

[1]

'

9.88%

[1]

'

8.50%

[1]

'

9.13%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.50%

[1]

'

'

'

'

5.95%

[1]

'

'

'

'

'

'

'

5.65%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

3.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.85%

'

'

'

2.50%

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

2.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.65%

'

'

5.38%

'

'

'

'

Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.06%

'

'

'

'

'

'

Proceeds from Issuance of Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

450,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Discount on Issuance

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.995

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unamortized Discount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit Facility, Maximum Borrowing Capacity, Amendment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

211,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Issuance Cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

23,000,000

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Convertible, Conversion Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$46.55

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Convertible, Conversion Ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21.4822

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt

'

23,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Increase (Decrease)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.25%

0.25%

1.00%

1.00%

Debt Instrument, Redemption Price, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

104.25%

103.81%

105.25%

106.99%

'

'

'

'

'

106.78%

'

'

'

104.20%

105.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, variable basis

'

'

'

'3 month LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

[1]

'

'

'LIBOR

[1]

'

'

'LIBOR

[1]

'

'

'

'

'

'

'

'

'

'

'LIBOR

[1]

'

'

'LIBOR

[1]

'

'

'LIBOR

[1]

'

'

'LIBOR

[1]

'

'

'

'

'

'

'

'

'

'

'LIBOR

[1]

'

'

'

'

'

'LIBOR

[1]

'

'

'

'LIBOR

[1]

'

'

'

'

'

'

'

'LIBOR

[1]

'

'

'

'

'

'

'

'

'LIBOR

[1]

'

'

'

'

'LIBOR

[1]

'

'

'3 month LIBOR

'

'3 month LIBOR

'

'6 month LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3-Month LIBOR

'3-Month LIBOR

'

'

'

'

'

'

'3-Month LIBOR

'3-Month LIBOR

'

'

'

'3-Month LIBOR

'3-Month LIBOR

'3-Month LIBOR

'

'

'

'3-Month LIBOR

'

'

'

'3-Month LIBOR

'6-Month LIBOR

'6-Month LIBOR

'

'

'

'6-Month LIBOR

'3-Month LIBOR

'3-Month LIBOR

'

'

'

'3-Month LIBOR

'3-Month LIBOR

'

'

'

'3-Month LIBOR

'3-Month LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

[1]

'

'

2.25%

[1]

'

'

2.75%

[1]

'

'

3.13%

[1]

'

'

'

'

'

'

'

'

'

2.75%

[1]

'

'

'

'

'

3.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

1.07%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

[1]

'

'

2.50%

'

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.88%

'

'

'

'

'

'

'

2.50%

'

'

'

'

'

2.25%

'

'

'

4.00%

'

'

'

'

'

2.75%

'

'

'

'

'

3.13%

'

'

'

'

2.88%

'

'

'

'

2.88%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, range, minimum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.34%

[1]

'

'

'

2.50%

[1]

2.40%

[1]

'

0.44%

[1]

'

'

'

'

'

'

'

'

'

7.12%

[1]

'

'

'

1.75%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, range, maximum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.78%

[1]

'

'

'

2.88%

[1]

3.63%

[1]

'

4.26%

[1]

'

'

'

'

'

'

'

'

'

7.25%

[1]

'

'

'

2.50%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, Chalk Point capital lease

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.19%

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase/redemption price, percentage of face amount (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

114.18%

'

'

111.70%

'

'

'

'

'

'

113.08%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustment to loss on debt extinguishment

40,000,000

'

21,000,000

81,000,000

49,000,000

'

22,000,000

33,000,000

'

'

'

'

'

'

'

'

'

'

'

28,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-11,000,000

'

'

'

'

18,000,000

'

'

'

'

'

'

'

'

'

-7,000,000

'

'

-3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Convertible Debt

'

345,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60,000,000

450,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchased/redeemed debt, face value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

575,000,000

575,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

407,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash paid for senior notes repurchases

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80,000,000

'

'

104,000,000

'

'

74,000,000

308,000,000

'

'

42,000,000

'

'

'

'

'

'

337,000,000

91,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Notional Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,123,000,000

'

'

'

44,000,000

'

'

'

'

'

'

'

176,000,000

'

'

'

'

60,000,000

368,000,000

'

'

'

'

'

'

'

'

48,000,000

179,000,000

'

'

'

'

63,000,000

102,000,000

'

'

'

'

23,000,000

'

'

'

'

60,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Repurchase Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$35,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

As of June 30, 2014, L+ equals 3 month LIBOR plus x%, with the exception of the NRG Solar Kansas South LLC and Viento Funding II term loan which is 6 month LIBOR plus x%.

Variable_Interest_Entities_Det

Variable Interest Entities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jul. 03, 2014	Jul. 03, 2014
			Capistrano Wind [Member]	GenConn Energy LLC	Sherbino I Wind Farm LLC	Texas Coastal Ventures LLC	Petra Nova Parish Holdings [Member]	Subsequent Event [Member]	Subsequent Event [Member]
			MW	facility			MW	Texas Coastal Ventures LLC	Petra Nova Parish Holdings [Member]
			powerplant	MW
Investments Accounted for by the Equity Method	'	'	'	'	'	'	'	'	'
Economic interest in equity method investments (as a percent)	'	'	'	50.00%	50.00%	50.00%	'	25.00%	'
Power generation units	'	'	'	2	'	'	'	'	'
Generation Capacity (in MW)	'	'	411	190	'	'	0	'	'
Equity investments in affiliates	$865,000,000	$453,000,000	'	$116,000,000	$80,000,000	$68,000,000	'	'	'
Equity Method Investments, Amount Sold	'	'	'	'	'	'	'	'	50.00%
Percentage of Ownership	'	'	100.00%	'	'	'	'	'	'
Power Generation Plants, Number	'	'	5	'	'	'	'	'	'
Cash Available for Distributions	'	'	1	'	'	'	'	'	'
Current assets	'	'	171,000,000	'	'	'	'	'	'
Net property, plant and equipment	'	'	644,000,000	'	'	'	'	'	'
Other long-term assets	'	'	6,000,000	'	'	'	'	'	'
Total assets	'	'	821,000,000	'	'	'	'	'	'
Current liabilities	'	'	29,000,000	'	'	'	'	'	'
Equity Method Investments, Summarized Financial Information, Long Term Debt	'	'	188,000,000	'	'	'	'	'	'
Other long-term liabilities	'	'	186,000,000	'	'	'	'	'	'
Total liabilities	'	'	403,000,000	'	'	'	'	'	'
Noncontrolling interests	'	'	$388,000,000	'	'	'	'	'	'

Changes_in_Capital_Structure_D

Changes in Capital Structure (Details)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Apr. 02, 2014	Sep. 30, 2014
			Long Term Incentive Plan [Member]	Employee Stock [Member]	Common Stock [Member]	Common Stock [Member]	Subsequent Event [Member]
					Edison Mission Energy [Member]	Edison Mission Energy [Member]
Capital Structure	'	'	'	'	'	'	'
Shares issued, balance at the beginning of the year	414,749,303	401,126,780	'	'	'	'	'
Stock Issued During Period, Shares, New Issues	'	'	950,546	'	'	'	'
Shares issued, balance at the end of the year	414,749,303	401,126,780	'	'	'	'	'
Shares outstanding, balance at the end of the year	337,473,370	323,779,252	950,546	71,595	12,671,977	'	'
Stock Issued During Period, Shares, Acquisitions	'	'	'	'	12,671,977	'	'
Treasury shares, balance at the beginning of the year	-77,275,933	-77,347,528	'	'	'	'	'
Treasury Stock, Shares, Acquired	'	'	0	71,595	0	'	'
Treasury shares, balance at the beginning of the year	-77,275,933	-77,347,528	'	'	'	'	'
Common stock authorized (in shares)	'	'	'	'	'	'	'
Common stock, shares authorized	500,000,000	'	'	'	'	'	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	'	'	'	'	'	12,671,977	'
Common Stock, Increase in Shares Available for Issuance under Employee Stock Purchase Plan	800,000	'	'	'	'	'	'
Common Stock, Capital Shares Reserved for Employee Stock Purchase Plan	1,616,793	'	'	'	'	'	'
Stock Issued During Period, Shares, Employee Stock Purchase Plans	'	'	'	'	'	'	56,845

Changes_in_Capital_Structure_D1

Changes in Capital Structure (Details 2) (USD $)	3 Months Ended			6 Months Ended		3 Months Ended	12 Months Ended
	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2014	Dec. 31, 2014
						Subsequent Event [Member]	Scenario, Plan [Member]
							Subsequent Event [Member]
Employee Stock Purchase Plan and 2013 Capital Allocation Plan	'	'	'	'	'	'	'
NRG's annual common stock dividend, proposed amount for 2013	'	'	'	'	'	'	$0.56
Dividend paid	$0.14	$0.12	$0.12	$0.26	$0.21	'	'
Dividend declared	'	'	'	'	'	$0.14	'

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Numerator:	'	'	'	'	'
Net Loss Attributable to NRG Energy, Inc.	($97)	$124	($153)	($208)	'
Dividends for preferred shares	3	3	5	5	'
(Loss)/earnings available for common stockholders	($100)	$121	($158)	($213)	'
Denominator:	'	'	'	'	'
Weighted average number of common shares outstanding	337	323	331	323	'
Basic earnings per share:	'	'	'	'	'
(Loss)/earnings per weighted average common share — basic	($0.30)	$0.37	($0.48)	($0.66)	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'	'	'
Antidilutive securities excluded from computation of diluted earnings per share, amount	24	18	24	27	'
3.625% convertible perpetual preferred stock, interest rate (as a percentage)	3.63%	3.63%	3.63%	3.63%	3.63%
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0	4	0	0	'
Equity compensation plans	'	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'	'	'
Antidilutive securities excluded from computation of diluted earnings per share, amount	8	2	8	11	'
Embedded derivative of 3.625% redeemable perpetual preferred stock	'	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'	'	'	'
Antidilutive securities excluded from computation of diluted earnings per share, amount	16	16	16	16	'

Segment_Reporting_Details

Segment Reporting (Details) (USD $)	3 Months Ended				6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013		Dec. 31, 2013
Segment Reporting Information	'		'		'		'		'
Operating revenues	$3,621		$2,929		$7,107		$5,010		'
Depreciation and amortization	386		313		721		620		'
Equity in earnings/(losses) of unconsolidated affiliates	14		8		21		11		'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-206		68		-304		-415		'
Net Loss Attributable to NRG Energy, Inc.	-97		124		-153		-208		'
Total Assets	37,629		'		37,629		'		33,902
Includes loss on debt extinguishment of	40		21		81		49		'
Retail	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	1,879	[1]	1,535	[2]	3,405	[3]	2,766	[4]	'
Depreciation and amortization	33	[1]	36	[2]	66	[3]	68	[4]	'
Equity in earnings/(losses) of unconsolidated affiliates	0	[1]	0	[2]	0	[3]	0	[4]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-111	[1]	-82	[2]	180	[3]	287	[4]	'
Net Loss Attributable to NRG Energy, Inc.	-112	[1]	-82	[2]	179	[3]	287	[4]	'
Total Assets	5,531	[1]	'		5,531	[1]	'		'
Includes intersegment sales and derivative gains and losses of	2		1		4		2		'
Conventional Power Generation | East	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	881	[1]	826	[2]	2,281	[3]	1,421	[4]	'
Depreciation and amortization	74	[1]	87	[2]	140	[3]	173	[4]	'
Equity in earnings/(losses) of unconsolidated affiliates	1	[1]	0	[2]	0	[3]	0	[4]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	6	[1]	133	[2]	225	[3]	-25	[4]	'
Net Loss Attributable to NRG Energy, Inc.	6	[1]	133	[2]	225	[3]	-25	[4]	'
Total Assets	10,260	[1]	'		10,260	[1]	'		'
Includes intersegment sales and derivative gains and losses of	-53		66		30		58		'
Conventional Power Generation | West	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	165	[1]	124	[2]	275	[3]	213	[4]	'
Depreciation and amortization	27	[1]	12	[2]	39	[3]	25	[4]	'
Equity in earnings/(losses) of unconsolidated affiliates	10	[1]	1	[2]	14	[3]	2	[4]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	33	[1]	36	[2]	41	[3]	32	[4]	'
Net Loss Attributable to NRG Energy, Inc.	33	[1]	36	[2]	41	[3]	32	[4]	'
Total Assets	2,158	[1]	'		2,158	[1]	'		'
Includes intersegment sales and derivative gains and losses of	0		3		0		3		'
Conventional Power Generation | Texas [Member]	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	1,003	[1]	963	[2]	1,477	[3]	1,243	[4]	'
Depreciation and amortization	144	[1]	136	[2]	287	[3]	273	[4]	'
Equity in earnings/(losses) of unconsolidated affiliates	1	[1]	1	[2]	1	[3]	2	[4]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	134	[1]	180	[2]	-203	[3]	-251	[4]	'
Net Loss Attributable to NRG Energy, Inc.	134	[1]	180	[2]	-203	[3]	-251	[4]	'
Total Assets	14,459	[1]	'		14,459	[1]	'		'
Includes intersegment sales and derivative gains and losses of	628		606		839		837		'
Alternative Energy	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	164	[1]	55	[2]	214	[3]	89	[4]	'
Depreciation and amortization	58	[1]	25	[2]	106	[3]	48	[4]	'
Equity in earnings/(losses) of unconsolidated affiliates	-2	[1]	-1	[2]	-6	[3]	1	[4]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	1	[1]	-13	[2]	-64	[3]	-28	[4]	'
Net Loss Attributable to NRG Energy, Inc.	-19	[1]	-22	[2]	-67	[3]	-38	[4]	'
Total Assets	8,381	[1]	'		8,381	[1]	'		'
Includes intersegment sales and derivative gains and losses of	4		0		4		0		'
NRG Yield	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	134	[1]	82	[2]	274	[3]	135	[4]	'
Depreciation and amortization	36	[1]	10	[2]	60	[3]	20	[4]	'
Equity in earnings/(losses) of unconsolidated affiliates	14	[1]	2	[2]	15	[3]	6	[4]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	36	[1]	35	[2]	65	[3]	46	[4]	'
Net Loss Attributable to NRG Energy, Inc.	28	[1]	35	[2]	50	[3]	46	[4]	'
Total Assets	3,236	[1]	'		3,236	[1]	'		'
Includes intersegment sales and derivative gains and losses of	0		0		0		0		'
Corporate	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	60	[1],[5]	26	[2],[6]	98	[3],[7]	57	[4],[8]	'
Depreciation and amortization	14	[1],[5]	7	[2],[6]	23	[3],[7]	13	[4],[8]	'
Equity in earnings/(losses) of unconsolidated affiliates	4	[1],[5]	0	[2],[6]	4	[3],[7]	0	[4],[8]	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-290	[1],[5]	-219	[2],[6]	-526	[3],[7]	-470	[4],[8]	'
Net Loss Attributable to NRG Energy, Inc.	-166	[1],[5]	-156	[2],[6]	-372	[3],[7]	-255	[4],[8]	'
Total Assets	28,311	[1],[5]	'		28,311	[1],[5]	'		'
Includes loss on debt extinguishment of	-40		-21		-81		-49		'
Includes intersegment sales and derivative gains and losses of	14		6		40		14		'
Elimination	'		'		'		'		'
Segment Reporting Information	'		'		'		'		'
Operating revenues	-665		-682		-917		-914		'
Depreciation and amortization	0		0		0		0		'
Equity in earnings/(losses) of unconsolidated affiliates	-14		5		-7		0		'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-15		-2		-22		-6		'
Net Loss Attributable to NRG Energy, Inc.	-1		0		-6		-4		'
Total Assets	($34,707)		'		($34,707)		'		'
[1]	(a) Operating revenues include inter-segment sales and net derivative gains and losses of:$2 $698 $(53) $— $4 $— $14
[2]	(c) Operating revenues include inter-segment sales and net derivative gains and losses of:$1 $606 $66 $3 $— $— $6
[3]	(e) Operating revenues include inter-segment sales and net derivative gains and losses of:$4 $839 $30 $— $4 $— $40
[4]	(g) Operating revenues include inter-segment sales and net derivative gains and losses of:$2 $837 $58 $3 $— $— $14
[5]	(b) Includes loss on debt extinguishment of $40 million
[6]	Includes loss on debt extinguishment of $21 million.
[7]	f) Includes loss on debt extinguishment of $81 million(In millions) Conventional Power Generation Six months ended June 30, 2013Retail(g) Gulf Coast(g) East(g) West(g) Renewables(g) NRG Yield(g) Corporate(g)(h) Elimination TotalOperating revenues$2,766 $1,243 $1,421 $213 $89 $135 $57 $(914) $5,010Depreciation and amortization68 273 173 25 48 20 13 — 620Equity in earnings of unconsolidated affiliates— 2 — 2 1 6 — — 11Income/(loss) before income taxes287 (251) (25) 32 (28) 46 (470) (6) (415)Net income/(loss) attributable to NRG Energy, Inc.$287 $(251) $(25) $32 $(38) $46 $(255) $(4) $(208)
[8]	(h) Includes loss on debt extinguishment of

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014													Jun. 30, 2013
Income Tax Disclosure [Abstract]	'	'	'													'
Document Period End Date	'	'	30-Jun-14													'
Effective Tax Rate	'	'	'													'
(Loss)/income before income taxes	($206)	$68	($304)													($415)
Income tax benefit	-126	-63	-157													-215
Effective tax rate (as a percent)	61.20%	-92.60%	51.60%													51.80%
Statutory tax rate (as a percent)	'	'	35.00%													35.00%
Schedule of Effective Income Tax Rate Reconciliation	'	'	'													'
			The income tax provision consisted of the following:
				Three months ended June 30,						Six months ended June 30,
			(In millions except otherwise noted)	2014			2013			2014			2013
			(Loss)/income before income taxes	$	(206	)	$	68		$	(304	)	$	(415	)
			Income tax benefit	(126		)	(63		)	(157		)	(215		)
			Effective tax rate	61.2		%	(92.6		)%	51.6		%	51.8		%
Uncertain Tax Benefits	'	'	'													'
Non-current tax liability for uncertain tax benefits	68	'	68													'
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	'	'	1													'
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	$15	'	$15													'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	6 Months Ended	1 Months Ended		1 Months Ended				1 Months Ended			6 Months Ended
	Jun. 30, 2014	Feb. 28, 2014	Apr. 30, 2012	Jun. 30, 2013	Mar. 31, 2013	Jan. 31, 2013	Mar. 31, 2014	Jun. 30, 2013	Mar. 31, 2014	Mar. 31, 2014	Jun. 30, 2014
		Big Cajun II Alleged Opacity Violations	Cheswick Class Action	Notice of Intent to File Citizens Suit	Notice of Intent to File Citizens Suit	Notice of Intent to File Citizens Suit	EME [Member]	GenOn Energy	GenOn Energy	U.S. District Court for the District of Nevada [Member]	Subsequent Event [Member]
			mi			permit		legal_cases	lawsuit	GenOn Energy	NRG Energy Center San Francisco LLC [Member]
								Lawsuits		Lawsuits
Loss Contingencies	'	'	'	'	'	'	'	'	'	'	'
Environmental Capital Expenditures, Estimated	$906,000,000	'	'	'	'	'	$439,000,000	'	'	'	'
Environmental Capital Expenditures, Estimated Total	'	'	'	'	'	'	350,000,000	'	'	'	'
Document Period End Date	30-Jun-14	'	'	'	'	'	'	'	'	'	'
Civil Penalties	'	'	'	100,000	'	'	'	'	'	'	'
Litigation Settlement, Amount	'	47,000	'	'	'	'	'	'	'	'	123,270
Distance From Facility of People who Own Property	'	'	1	'	'	'	'	'	'	'	'
Minimum Civil Penalties which May Be Assumed	$200,000	'	'	'	'	'	'	'	'	'	'
Loss Contingency, Claims Settled and Dismissed, Number	'	'	'	'	'	'	'	1	'	'	'
Loss Contingency, Pending Claims, Number	'	'	'	'	'	'	'	5	5	4	'
Number of Permits that Regulate Polution Discharge Elimination	'	'	'	'	'	3	'	'	'	'	'
Loss Contingency, Number of Days to Comply with Discharge Violation	'	'	'	'	'60 days	'	'	'	'	'	'

Environmental_Matters_Details

Environmental Matters (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2014
		Midwest Generation [Member]	EME [Member]	Interest Expense [Member]
				Midwest Generation [Member]
Environmental capital expenditures [Line Items]	'	'	'	'
Environmental Capital Expenditures, Estimated	$906,000,000	$567,000,000	$439,000,000	$22,000,000
Environmental Capital Expenditures, Estimated Total	'	'	350,000,000	'
Estimated environmental capital expenditures from 2013 through 2017, attributable to GenOn	123,000,000	'	'	'
Minimum Civil Penalties which May Be Assumed	$200,000	'	'	'

Condensed_Consolidating_Financ2

Condensed Consolidating Financial Information (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument	'	'
Long-term Debt	$18,988	$16,804
Recourse Debt	'	'
Debt Instrument	'	'
Long-term Debt	8,999	8,087
Senior Notes [Member] | Recourse Debt	'	'
Debt Instrument	'	'
Long-term Debt	$6,600	'

Condensed_Consolidating_Financ3

Condensed Consolidating Financial Information (Details 2) (USD $)	3 Months Ended				6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Operating Revenues	'		'		'		'
Total operating revenues	$3,621		$2,929		$7,107		$5,010
Operating Costs and Expenses	'		'		'		'
Cost of operations	2,817		2,051		5,550		3,804
Depreciation and amortization	386		313		721		620
Selling, general and administrative	268		230		494		457
Acquisition-related transaction and integration costs	40		27		52		69
Development activity expenses	21		21		40		39
Total operating costs and expenses	3,532		2,642		6,857		4,989
Gain (Loss) on Disposition of Property Plant Equipment	'		'		19		0
Operating Income (Loss)	89		287		269		21
Other Income/(Expense)	'		'		'		'
Equity in earnings/(losses) of consolidated subsidiaries	0		0		0		0
Other income, net	5		0		16		4
Loss on debt extinguishment	-40		-21		-81		-49
Interest expense	-274		-206		-529		-402
Total other expense	-295		-219		-573		-436
(Loss)/Income Before Income Taxes	-206		68		-304		-415
Income tax expense/(benefit)	-126		-63		-157		-215
Net (Loss)/Income	-80		131		-147		-200
Less: Net income attributable to noncontrolling interest	17		7		6		8
Net (Loss)/Income Attributable to NRG Energy, Inc.	-97		124		-153		-208
Other Comprehensive Income/(Loss), net of tax	'		'		'		'
Unrealized (loss)/gain on derivatives, net	-19		17		-28		24
Foreign currency translation adjustments, net	-3		-19		3		-19
Available-for-sale securities, net	7		0		13		2
Defined benefit plan, net	10		20		12		25
Other comprehensive income	-5		18		0		32
Comprehensive income/(loss)	-85		149		-147		-168
Comprehensive loss attributable to noncontrolling interest	12		7		-3		8
Comprehensive (Loss)/Income Attributable to NRG Energy, Inc.	-97		142		-144		-176
Dividends for preferred shares	-3		-3		-5		-5
Comprehensive Income/(Loss) Available for Common Stockholders	-100		139		-149		-181
Equity in earnings of unconsolidated affiliates	14		8		21		11
Guarantor Subsidiaries	'		'		'		'
Operating Revenues	'		'		'		'
Total operating revenues	2,514		2,171		4,793		3,761
Operating Costs and Expenses	'		'		'		'
Cost of operations	2,048		1,647		3,841		2,905
Depreciation and amortization	211		207		409		411
Selling, general and administrative	106		110		211		225
Acquisition-related transaction and integration costs	0		0		0		0
Development activity expenses	0		0		0		0
Total operating costs and expenses	2,365		1,964		4,461		3,541
Gain (Loss) on Disposition of Property Plant Equipment	'		'		0		'
Operating Income (Loss)	149		207		332		220
Other Income/(Expense)	'		'		'		'
Equity in earnings/(losses) of consolidated subsidiaries	52		20		101		21
Other income, net	3		1		4		2
Loss on debt extinguishment	0		0		0		0
Interest expense	5		5		-11		10
Total other expense	56		17		104		15
(Loss)/Income Before Income Taxes	205		224		436		235
Income tax expense/(benefit)	47		65		110		86
Net (Loss)/Income	158		159		326		149
Less: Net income attributable to noncontrolling interest	0		0		0		0
Net (Loss)/Income Attributable to NRG Energy, Inc.	158		159		326		149
Other Comprehensive Income/(Loss), net of tax	'		'		'		'
Unrealized (loss)/gain on derivatives, net	2		-32		8		-41
Foreign currency translation adjustments, net	0		0		0		0
Available-for-sale securities, net	0		'		0		0
Defined benefit plan, net	2		0		0		0
Other comprehensive income	0		-32		8		-41
Comprehensive income/(loss)	158		127		334		108
Comprehensive loss attributable to noncontrolling interest	0		0		0		0
Comprehensive (Loss)/Income Attributable to NRG Energy, Inc.	158		127		334		108
Dividends for preferred shares	0		0		0		0
Comprehensive Income/(Loss) Available for Common Stockholders	158		127		334		108
Equity in earnings of unconsolidated affiliates	6		1		10		2
Non-Guarantor Subsidiaries	'		'		'		'
Operating Revenues	'		'		'		'
Total operating revenues	1,129		850		2,380		1,375
Operating Costs and Expenses	'		'		'		'
Cost of operations	762		492		1,736		1,007
Depreciation and amortization	170		103		304		203
Selling, general and administrative	82		66		139		118
Acquisition-related transaction and integration costs	7		12		8		41
Development activity expenses	7		7		17		13
Total operating costs and expenses	1,028		680		2,204		1,382
Gain (Loss) on Disposition of Property Plant Equipment	'		'		19		'
Operating Income (Loss)	101		170		195		-7
Other Income/(Expense)	'		'		'		'
Equity in earnings/(losses) of consolidated subsidiaries	0		-2		-6		-4
Other income, net	4		-2		8		0
Loss on debt extinguishment	0		-11		-9		-11
Interest expense	120		77		-227		141
Total other expense	-99		-88		-216		-150
(Loss)/Income Before Income Taxes	2		82		-21		-157
Income tax expense/(benefit)	4		11		-6		-74
Net (Loss)/Income	-2		71		-15		-83
Less: Net income attributable to noncontrolling interest	39		4		36		5
Net (Loss)/Income Attributable to NRG Energy, Inc.	-41		67		-51		-88
Other Comprehensive Income/(Loss), net of tax	'		'		'		'
Unrealized (loss)/gain on derivatives, net	-20		44		-26		49
Foreign currency translation adjustments, net	-1		-15		5		-15
Available-for-sale securities, net	5		'		5		0
Defined benefit plan, net	13		-25		13		-25
Other comprehensive income	-29		54		-29		59
Comprehensive income/(loss)	-31		125		-44		-24
Comprehensive loss attributable to noncontrolling interest	0		9		27		10
Comprehensive (Loss)/Income Attributable to NRG Energy, Inc.	-63		116		-71		-34
Dividends for preferred shares	0		0		0		0
Comprehensive Income/(Loss) Available for Common Stockholders	-63		116		-71		-34
Equity in earnings of unconsolidated affiliates	17		4		18		6
NRG Energy, Inc.	'		'		'		'
Operating Revenues	'		'		'		'
Total operating revenues	0		0		0		0
Operating Costs and Expenses	'		'		'		'
Cost of operations	11		0		7		7
Depreciation and amortization	5		3		8		6
Selling, general and administrative	80		58		144		125
Acquisition-related transaction and integration costs	33		15		44		28
Development activity expenses	14		14		23		26
Total operating costs and expenses	143		90		226		192
Gain (Loss) on Disposition of Property Plant Equipment	'		'		0		'
Operating Income (Loss)	-143		-90		-226		-192
Other Income/(Expense)	'		'		'		'
Equity in earnings/(losses) of consolidated subsidiaries	65		208		180		44
Other income, net	-2		1		5		2
Loss on debt extinguishment	-40		-10		-72		-38
Interest expense	149		124		-292		251
Total other expense	-126		75		-179		-243
(Loss)/Income Before Income Taxes	-269		-15		-405		-435
Income tax expense/(benefit)	-177		-139		-261		-227
Net (Loss)/Income	-92		124		-144		-208
Less: Net income attributable to noncontrolling interest	5		0		9		0
Net (Loss)/Income Attributable to NRG Energy, Inc.	-97		124		-153		-208
Other Comprehensive Income/(Loss), net of tax	'		'		'		'
Unrealized (loss)/gain on derivatives, net	-8		-15		-3		-8
Foreign currency translation adjustments, net	-2		-4		-2		-4
Available-for-sale securities, net	4		'		8		2
Defined benefit plan, net	-25		5		25		0
Other comprehensive income	19		-24		28		-10
Comprehensive income/(loss)	-73		100		-116		-218
Comprehensive loss attributable to noncontrolling interest	5		0		9		0
Comprehensive (Loss)/Income Attributable to NRG Energy, Inc.	-78		100		-125		-218
Dividends for preferred shares	-3		-3		-5		-5
Comprehensive Income/(Loss) Available for Common Stockholders	-81		97		-130		-223
Equity in earnings of unconsolidated affiliates	0		0		0		0
Eliminations	'		'		'		'
Operating Revenues	'		'		'		'
Total operating revenues	-22	[1]	-92	[1]	-66	[2]	-126	[1]
Operating Costs and Expenses	'		'		'		'
Cost of operations	-4	[1]	-88	[1]	-34	[2]	-115	[1]
Depreciation and amortization	0	[1]	0	[1]	0	[2]	0	[1]
Selling, general and administrative	0	[1]	-4	[1]	0	[2]	-11	[1]
Acquisition-related transaction and integration costs	0	[1]	0	[1]	0	[2]	0	[1]
Development activity expenses	0	[1]	0	[1]	0	[2]	0	[1]
Total operating costs and expenses	-4	[1]	-92	[1]	-34	[2]	-126	[1]
Gain (Loss) on Disposition of Property Plant Equipment	'		'		0	[2]	'
Operating Income (Loss)	-18	[1]	0	[1]	-32	[2]	0	[1]
Other Income/(Expense)	'		'		'		'
Equity in earnings/(losses) of consolidated subsidiaries	-117	[1]	-226	[1]	-275	[2]	-61	[1]
Other income, net	0	[1]	0	[1]	-1	[2]	0	[1]
Loss on debt extinguishment	0	[1]	0	[1]	0	[2]	0	[1]
Interest expense	0	[1]	0	[1]	1	[2]	0	[1]
Total other expense	-126	[1]	-223	[1]	-282	[2]	-58	[1]
(Loss)/Income Before Income Taxes	-144	[1]	-223	[1]	-314	[2]	-58	[1]
Income tax expense/(benefit)	0	[1]	0	[1]	0	[2]	0	[1]
Net (Loss)/Income	-144	[1]	-223	[1],[3]	-314	[1],[2]	-58	[1]
Less: Net income attributable to noncontrolling interest	-27	[1]	3	[1]	-39	[2]	3	[1]
Net (Loss)/Income Attributable to NRG Energy, Inc.	-117	[1]	-226	[1]	-275	[2]	-61	[1]
Other Comprehensive Income/(Loss), net of tax	'		'		'		'
Unrealized (loss)/gain on derivatives, net	7	[1]	20	[3]	-7	[1]	24	[1]
Foreign currency translation adjustments, net	0	[1]	0	[3]	0	[1]	0	[1]
Available-for-sale securities, net	-2	[1]	'		0	[1]	0	[1]
Defined benefit plan, net	0	[1]	0	[3]	0	[1]	0	[1]
Other comprehensive income	5	[1]	20	[3]	-7	[1]	24	[1]
Comprehensive income/(loss)	-139	[1]	-203	[3]	-321	[1]	-34	[1]
Comprehensive loss attributable to noncontrolling interest	0	[1]	-2	[3]	-39	[1]	-2	[1]
Comprehensive (Loss)/Income Attributable to NRG Energy, Inc.	-114	[1]	-201	[3]	-282	[1]	-32	[1]
Dividends for preferred shares	0	[1]	0	[3]	0	[1]	0	[1]
Comprehensive Income/(Loss) Available for Common Stockholders	-114	[1]	-201	[3]	-282	[1]	-32	[1]
Equity in earnings of unconsolidated affiliates	($9)	[1]	$3	[1]	($7)	[2]	$3	[1]
[1]	(a)All significant intercompany transactions have been eliminated in consolidation.
[2]	(a)All significant intercompany transactions have been eliminated in consolidation.NRG ENERGY, INC. AND SUBSIDIARIESCONDENSED CONSOLIDATING STATEMENTS OF OPERATIONSFor the Six Months Ended June 30, 2014 (Unaudited) Guarantor Subsidiaries Non-Guarantor Subsidiaries NRG Energy, Inc. (Note Issuer) Eliminations(a) Consolidated (In millions)Operating Revenues Total operating revenues$4,793 $2,380 $— $(66) $7,107Operating Costs and Expenses Cost of operations3,841 1,736 7 (34) 5,550Depreciation and amortization409 304 8 — 721Selling, general and administrative211 139 144 — 494Acquisition-related transaction and integration costs— 8 44 — 52Development activity expenses— 17 23 — 40Total operating costs and expenses4,461 2,204 226 (34) 6,857Gain on sale of assets— 19 — — 19Operating Income/(Loss)332 195 (226) (32) 269Other Income/(Expense) Equity in earnings/(loss) of consolidated subsidiaries101 (6) 180 (275) —Equity in earnings of unconsolidated affiliates10 18 — (7) 21Other income, net4 8 5 (1) 16Loss on debt extinguishment— (9) (72) — (81)Interest expense(11) (227) (292) 1 (529)Total other income/(expense)104 (216) (179) (282) (573)Income/(Loss) Before Income Taxes436 (21) (405) (314) (304)Income tax expense/(benefit)110 (6) (261) — (157)Net Income/(Loss)326 (15) (144) (314) (147)Less: Net income attributable to noncontrolling interest— 36 9 (39) 6Net Income/(Loss) attributable to NRG Energy, Inc.$326 $(51) $(153) $(275) $(153)(a)All significant intercompany transactions have been eliminated in consolidation.
[3]	All significant intercompany transactions have been eliminated in consolidation.

Condensed_Consolidating_Financ4

Condensed Consolidating Financial Information (Details 3) (USD $)	Jun. 30, 2014		Dec. 31, 2013		Jun. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'		'		'		'
Cash and cash equivalents	$1,481		$2,254		$1,368		$2,087
Funds deposited by counterparties	9		63		'		'
Restricted cash	286		268		'		'
Accounts receivable-trade, net	1,482		1,214		'		'
Inventory	996		898		'		'
Derivative instruments	1,701		1,328		'		'
Deferred income taxes	79		258		'		'
Cash collateral paid in support of energy risk management activities	572		276		'		'
Due from Affiliate, Current	10		'		'		'
Renewable energy grant receivable, net	614		539		'		'
Prepayments and other current assets	527		498		'		'
Total current assets	7,757		7,596		'		'
Net property, plant and equipment	21,576		19,851		'		'
Other Assets	'		'		'		'
Investment in subsidiaries	0		0		'		'
Equity investments in affiliates	865		453		'		'
Capital leases and notes receivable, less current portion	85		73		'		'
Goodwill	2,116		1,985		'		'
Intangible assets, net	1,434		1,140		'		'
Nuclear decommissioning trust fund	576		551		'		'
Deferred income taxes	1,500		1,202		'		'
Derivative instruments	413		311		'		'
Other non-current assets	1,307		740		'		'
Other non-current assets	1,307		740		'		'
Total other assets	8,296		6,455		'		'
Total Assets	37,629		33,902		'		'
Current Liabilities	'		'		'		'
Current portion of long-term debt and capital leases	833		1,050		'		'
Accounts payable	1,103		1,038		'		'
Accounts payable — affiliate	0		0		'		'
Derivative instruments	1,736		1,055		'		'
Cash collateral received in support of energy risk management activities	9		63		'		'
Accrued expenses and other current liabilities	1,065		998		'		'
Total current liabilities	4,746		4,204		'		'
Other Liabilities	'		'		'		'
Long-term debt and capital leases	18,165		15,767		'		'
Nuclear decommissioning reserve	302		294		'		'
Nuclear decommissioning reserve	336		324		'		'
Deferred income taxes	71		22		'		'
Derivative instruments	354		195		'		'
Out-of-market contracts	1,175		1,177		'		'
Other non-current liabilities	1,254		1,201		'		'
Total non-current liabilities	21,657		18,980		'		'
Total Liabilities	26,403		23,184		'		'
3.625% convertible perpetual preferred stock	249		249		'		'
3.625% convertible perpetual preferred stock, interest rate (as a percentage)	3.63%		3.63%		3.63%		'
Total Stockholders' Equity	10,977		10,469		'		'
Total Liabilities and Stockholders' Equity	37,629		33,902		'		'
Guarantor Subsidiaries	'		'		'		'
Current Assets	'		'		'		'
Cash and cash equivalents	25		56		72		78
Funds deposited by counterparties	5		7		'		'
Restricted cash	9		12		'		'
Accounts receivable-trade, net	1,205		965		'		'
Inventory	419		436		'		'
Derivative instruments	989		866		'		'
Deferred income taxes	0		0		'		'
Cash collateral paid in support of energy risk management activities	282		214		'		'
Due from Affiliate, Current	5,661		'		'		'
Renewable energy grant receivable, net	0		0		'		'
Prepayments and other current assets	128		4,778		'		'
Total current assets	8,723		7,334		'		'
Net property, plant and equipment	8,884		9,116		'		'
Other Assets	'		'		'		'
Investment in subsidiaries	573		32		'		'
Equity investments in affiliates	-20		-30		'		'
Capital leases and notes receivable, less current portion	0		0		'		'
Goodwill	2,064		1,973		'		'
Intangible assets, net	958		925		'		'
Nuclear decommissioning trust fund	576		551		'		'
Deferred income taxes	8		'		'		'
Derivative instruments	172		110		'		'
Other non-current assets	96		76		'		'
Total other assets	4,427		3,637		'		'
Total Assets	22,034		20,087		'		'
Current Liabilities	'		'		'		'
Current portion of long-term debt and capital leases	1		1		'		'
Accounts payable	748		652		'		'
Accounts payable — affiliate	1,054		1,350		'		'
Derivative instruments	1,029		859		'		'
Cash collateral received in support of energy risk management activities	5		6		'		'
Accrued expenses and other current liabilities	283		297		'		'
Total current liabilities	3,120		3,165		'		'
Other Liabilities	'		'		'		'
Long-term debt and capital leases	316		317		'		'
Nuclear decommissioning reserve	302		294		'		'
Nuclear decommissioning reserve	336		324		'		'
Deferred income taxes	1,142		1,024		'		'
Derivative instruments	189		147		'		'
Out-of-market contracts	119		127		'		'
Other non-current liabilities	424		412		'		'
Total non-current liabilities	2,828		2,645		'		'
Total Liabilities	5,948		5,810		'		'
3.625% convertible perpetual preferred stock	0		0		'		'
Total Stockholders' Equity	16,086		14,277		'		'
Total Liabilities and Stockholders' Equity	22,034		20,087		'		'
Non-Guarantor Subsidiaries	'		'		'		'
Current Assets	'		'		'		'
Cash and cash equivalents	1,121		870		475		1,258
Funds deposited by counterparties	4		56		'		'
Restricted cash	276		252		'		'
Accounts receivable-trade, net	277		249		'		'
Inventory	577		462		'		'
Derivative instruments	852		470		'		'
Deferred income taxes	41		41		'		'
Cash collateral paid in support of energy risk management activities	290		62		'		'
Due from Affiliate, Current	821		'		'		'
Renewable energy grant receivable, net	614		539		'		'
Prepayments and other current assets	367		379		'		'
Total current assets	5,240		3,380		'		'
Net property, plant and equipment	12,563		10,604		'		'
Other Assets	'		'		'		'
Investment in subsidiaries	-932		422		'		'
Equity investments in affiliates	1,014		583		'		'
Capital leases and notes receivable, less current portion	73		62		'		'
Goodwill	52		12		'		'
Intangible assets, net	545		232		'		'
Nuclear decommissioning trust fund	0		0		'		'
Deferred income taxes	586		681		'		'
Derivative instruments	269		202		'		'
Other non-current assets	637		281		'		'
Total other assets	2,244		2,475		'		'
Total Assets	20,047		16,459		'		'
Current Liabilities	'		'		'		'
Current portion of long-term debt and capital leases	813		1,029		'		'
Accounts payable	325		352		'		'
Accounts payable — affiliate	365		760		'		'
Derivative instruments	847		204		'		'
Cash collateral received in support of energy risk management activities	4		57		'		'
Accrued expenses and other current liabilities	491		410		'		'
Total current liabilities	2,845		2,812		'		'
Other Liabilities	'		'		'		'
Long-term debt and capital leases	9,272		7,837		'		'
Nuclear decommissioning reserve	0		0		'		'
Nuclear decommissioning reserve	0		0		'		'
Deferred income taxes	-1,003		-1,002		'		'
Derivative instruments	194		49		'		'
Out-of-market contracts	1,056		1,050		'		'
Other non-current liabilities	583		615		'		'
Total non-current liabilities	10,102		8,549		'		'
Total Liabilities	12,947		11,361		'		'
3.625% convertible perpetual preferred stock	0		0		'		'
Total Stockholders' Equity	7,100		5,098		'		'
Total Liabilities and Stockholders' Equity	20,047		16,459		'		'
NRG Energy, Inc.	'		'		'		'
Current Assets	'		'		'		'
Cash and cash equivalents	335		1,328		821		751
Funds deposited by counterparties	0		0		'		'
Restricted cash	1		4		'		'
Accounts receivable-trade, net	0		0		'		'
Inventory	0		0		'		'
Derivative instruments	0		0		'		'
Deferred income taxes	38		217		'		'
Cash collateral paid in support of energy risk management activities	0		0		'		'
Due from Affiliate, Current	-4,748		'		'		'
Renewable energy grant receivable, net	0		0		'		'
Prepayments and other current assets	32		-3,802		'		'
Total current assets	-4,342		-2,253		'		'
Net property, plant and equipment	153		153		'		'
Other Assets	'		'		'		'
Investment in subsidiaries	22,474		18,266		'		'
Equity investments in affiliates	0		0		'		'
Capital leases and notes receivable, less current portion	108		105		'		'
Goodwill	'		0		'		'
Intangible assets, net	-47		4		'		'
Nuclear decommissioning trust fund	0		0		'		'
Deferred income taxes	906		521		'		'
Derivative instruments	0		0		'		'
Other non-current assets	574		383		'		'
Total other assets	24,015		19,279		'		'
Total Assets	19,826		17,179		'		'
Current Liabilities	'		'		'		'
Current portion of long-term debt and capital leases	19		20		'		'
Accounts payable	30		34		'		'
Accounts payable — affiliate	305		-1,253		'		'
Derivative instruments	0		0		'		'
Cash collateral received in support of energy risk management activities	0		0		'		'
Accrued expenses and other current liabilities	291		291		'		'
Total current liabilities	645		-908		'		'
Other Liabilities	'		'		'		'
Long-term debt and capital leases	8,673		7,707		'		'
Nuclear decommissioning reserve	0		0		'		'
Nuclear decommissioning reserve	0		0		'		'
Deferred income taxes	-68		0		'		'
Derivative instruments	0		0		'		'
Out-of-market contracts	0		0		'		'
Other non-current liabilities	247		174		'		'
Total non-current liabilities	8,852		7,881		'		'
Total Liabilities	9,497		6,973		'		'
3.625% convertible perpetual preferred stock	249		249		'		'
3.625% convertible perpetual preferred stock, interest rate (as a percentage)	3.63%		3.63%		'		'
Total Stockholders' Equity	10,080		9,957		'		'
Total Liabilities and Stockholders' Equity	19,826		17,179		'		'
Eliminations	'		'		'		'
Current Assets	'		'		'		'
Cash and cash equivalents	0	[1]	0	[1]	0	[1]	0	[1]
Funds deposited by counterparties	0	[1]	0	[1]	'		'
Restricted cash	0	[1]	0	[1]	'		'
Accounts receivable-trade, net	0	[1]	0	[1]	'		'
Inventory	0	[1]	0	[1]	'		'
Derivative instruments	-140	[1]	-8	[1]	'		'
Deferred income taxes	0	[1]	0	[1]	'		'
Cash collateral paid in support of energy risk management activities	0	[1]	0	[1]	'		'
Due from Affiliate, Current	-1,724	[1]	'		'		'
Renewable energy grant receivable, net	0	[1]	0	[1]	'		'
Prepayments and other current assets	0	[1]	-857	[1]	'		'
Total current assets	-1,864	[1]	-865	[1]	'		'
Net property, plant and equipment	-24	[1]	-22	[1]	'		'
Other Assets	'		'		'		'
Investment in subsidiaries	-22,115	[1]	-18,720	[1]	'		'
Equity investments in affiliates	-129	[1]	-100	[1]	'		'
Capital leases and notes receivable, less current portion	-96	[1]	-94	[1]	'		'
Goodwill	0	[1]	0	[1]	'		'
Intangible assets, net	-22	[1]	-21	[1]	'		'
Nuclear decommissioning trust fund	0	[1]	0	[1]	'		'
Deferred income taxes	0	[1]	0	[1]	'		'
Derivative instruments	-28	[1]	-1	[1]	'		'
Other non-current assets	'	[1]	0	[1]	'		'
Total other assets	-22,390	[1]	-18,936	[1]	'		'
Total Assets	-24,278	[1]	-19,823	[1]	'		'
Current Liabilities	'		'		'		'
Current portion of long-term debt and capital leases	0	[1]	0	[1]	'		'
Accounts payable	0	[1]	0	[1]	'		'
Accounts payable — affiliate	-1,724	[1]	-857	[1]	'		'
Derivative instruments	-140	[1]	-8	[1]	'		'
Cash collateral received in support of energy risk management activities	0	[1]	0	[1]	'		'
Accrued expenses and other current liabilities	'	[1]	0	[1]	'		'
Total current liabilities	-1,864	[1]	-865	[1]	'		'
Other Liabilities	'		'		'		'
Long-term debt and capital leases	-96	[1]	-94	[1]	'		'
Nuclear decommissioning reserve	0	[1]	0	[1]	'		'
Nuclear decommissioning reserve	0	[1]	0	[1]	'		'
Deferred income taxes	0	[1]	0	[1]	'		'
Derivative instruments	-29	[1]	-1	[1]	'		'
Out-of-market contracts	0	[1]	0	[1]	'		'
Other non-current liabilities	'	[1]	0	[1]	'		'
Total non-current liabilities	-125	[1]	-95	[1]	'		'
Total Liabilities	-1,989	[1]	-960	[1]	'		'
3.625% convertible perpetual preferred stock	0	[1]	0	[1]	'		'
Total Stockholders' Equity	-22,289	[1]	-18,863	[1]	'		'
Total Liabilities and Stockholders' Equity	($24,278)	[1]	($19,823)	[1]	'		'
[1]	All significant intercompany transactions have been eliminated in consolidation.

Condensed_Consolidating_Financ5

Condensed Consolidating Financial Information (Details 4) (USD $)	3 Months Ended				6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Cash Flows from Operating Activities	'		'		'		'
Net (Loss)/Income	($80)		$131		($147)		($200)
Adjustments to reconcile net loss to net cash provided/(used) by operating activities:	'		'		'		'
Distributions and equity in (earnings)/losses of unconsolidated affiliates and consolidated subsidiaries	'		'		39		5
Depreciation and amortization	386		313		721		620
Provision for bad debts	'		'		30		23
Amortization of nuclear fuel	'		'		20		16
Amortization of financing costs and debt discount/premiums	'		'		-9		-26
Amortization of intangibles and out-of-market contracts	'		'		22		124
Amortization of unearned equity compensation	'		'		24		24
Changes in deferred income taxes and liability for uncertain tax benefits	'		'		-514		-224
Changes in nuclear decommissioning trust liability	'		'		6		25
Changes in derivative instruments	'		'		535		174
Changes in collateral deposits supporting energy risk management activities	'		'		-297		-158
Cash used by changes in other working capital	'		'		-64		-465
Net Cash (Used)/Provided by Operating Activities	'		'		370		-78
Cash Flows from Investing Activities	'		'		'		'
Intercompany loans to subsidiaries	'		'		0		0
Acquisitions of businesses, net of cash acquired	'		'		-1,817		-39
Capital expenditures	'		'		-507		-1,281
Increase in restricted cash, net	'		'		-6		-31
Increase in restricted cash - U.S. DOE projects	'		'		21		-16
Decrease/(increase) in notes receivable	'		'		-2		11
Investments in nuclear decommissioning trust fund securities	'		'		-340		-233
Proceeds from sales of nuclear decommissioning trust fund securities	'		'		334		208
Proceeds from renewable energy grants	'		'		429		48
Proceeds from sale of assets, net of cash disposed of	'		'		77		0
Cash proceeds to fund cash grant bridge loan payment	'		'		57		0
Other	'		'		-3		-20
Net Cash Provided/(Used) by Investing Activities	'		'		-1,753		-1,375
Cash Flows from Financing Activities	'		'		'		'
Proceeds from intercompany loans	'		'		0		0
Payment of dividends to common and preferred stockholders	'		'		-91		-73
Payment of intercompany dividends	'		'		'		-73
Payment for treasury stock	'		'		0		-25
Net (payments for)/receipts from settlement of acquired derivatives that include financing elements	'		'		-167		171
Contributions and sale proceeds from noncontrolling interest in subsidiaries	'		'		-10		-33
Proceeds from issuance of long-term debt	'		'		3,886		1,472
Proceeds from issuance of common stock	'		'		8		9
Payment of debt issuance costs	'		'		-43		-35
Payments for short and long-term debt	'		'		-2,969		-816
Net Cash (Used)/Provided by Financing Activities	'		'		634		736
Effect of exchange rate changes on cash and cash equivalents	'		'		-24		-2
Net Increase/(Decrease) in Cash and Cash Equivalents	'		'		-773		-719
Cash and Cash Equivalents at Beginning of Period	'		'		2,254		2,087
Cash and Cash Equivalents at End of Period	1,481		1,368		1,481		1,368
Guarantor Subsidiaries	'		'		'		'
Cash Flows from Operating Activities	'		'		'		'
Net (Loss)/Income	158		159		326		149
Adjustments to reconcile net loss to net cash provided/(used) by operating activities:	'		'		'		'
Depreciation and amortization	211		207		409		411
Net Cash (Used)/Provided by Operating Activities	'		'		798		664
Cash Flows from Investing Activities	'		'		'		'
Intercompany loans to subsidiaries	'		'		-808		-393
Acquisitions of businesses, net of cash acquired	'		'		0		0
Capital expenditures	'		'		-9		-196
Increase in restricted cash, net	'		'		-2		-2
Increase in restricted cash - U.S. DOE projects	'		'		0		0
Decrease/(increase) in notes receivable	'		'		0		-3
Investments in nuclear decommissioning trust fund securities	'		'		-340		-233
Proceeds from sales of nuclear decommissioning trust fund securities	'		'		334		208
Proceeds from renewable energy grants	'		'		0		0
Proceeds from sale of assets, net of cash disposed of	'		'		0		'
Cash proceeds to fund cash grant bridge loan payment	'		'		0		'
Other	'		'		-4		-8
Net Cash Provided/(Used) by Investing Activities	'		'		-829		-621
Cash Flows from Financing Activities	'		'		'		'
Proceeds from intercompany loans	'		'		0		0
Payment of dividends to common and preferred stockholders	'		'		0		'
Payment of intercompany dividends	'		'		'		0
Payment for treasury stock	'		'		'		0
Net (payments for)/receipts from settlement of acquired derivatives that include financing elements	'		'		0		-49
Contributions and sale proceeds from noncontrolling interest in subsidiaries	'		'		0		0
Proceeds from issuance of long-term debt	'		'		0		0
Proceeds from issuance of common stock	'		'		0		0
Payment of debt issuance costs	'		'		0		0
Payments for short and long-term debt	'		'		0		0
Net Cash (Used)/Provided by Financing Activities	'		'		0		-49
Effect of exchange rate changes on cash and cash equivalents	'		'		0		0
Net Increase/(Decrease) in Cash and Cash Equivalents	'		'		-31		-6
Cash and Cash Equivalents at Beginning of Period	'		'		56		78
Cash and Cash Equivalents at End of Period	25		72		25		72
Non-Guarantor Subsidiaries	'		'		'		'
Cash Flows from Operating Activities	'		'		'		'
Net (Loss)/Income	-2		71		-15		-83
Adjustments to reconcile net loss to net cash provided/(used) by operating activities:	'		'		'		'
Depreciation and amortization	170		103		304		203
Net Cash (Used)/Provided by Operating Activities	'		'		641		-288
Cash Flows from Investing Activities	'		'		'		'
Intercompany loans to subsidiaries	'		'		-552		3
Acquisitions of businesses, net of cash acquired	'		'		-25		-39
Capital expenditures	'		'		-134		-1,081
Increase in restricted cash, net	'		'		-5		-30
Increase in restricted cash - U.S. DOE projects	'		'		24		-10
Decrease/(increase) in notes receivable	'		'		-2		6
Investments in nuclear decommissioning trust fund securities	'		'		0		0
Proceeds from sales of nuclear decommissioning trust fund securities	'		'		0		0
Proceeds from renewable energy grants	'		'		429		48
Proceeds from sale of assets, net of cash disposed of	'		'		0		'
Cash proceeds to fund cash grant bridge loan payment	'		'		57		'
Other	'		'		1		-12
Net Cash Provided/(Used) by Investing Activities	'		'		-203		-1,127
Cash Flows from Financing Activities	'		'		'		'
Proceeds from intercompany loans	'		'		0		0
Payment of dividends to common and preferred stockholders	'		'		0		'
Payment of intercompany dividends	'		'		'		0
Payment for treasury stock	'		'		'		0
Net (payments for)/receipts from settlement of acquired derivatives that include financing elements	'		'		-167		220
Contributions and sale proceeds from noncontrolling interest in subsidiaries	'		'		-10		-33
Proceeds from issuance of long-term debt	'		'		551		995
Proceeds from issuance of common stock	'		'		0		0
Payment of debt issuance costs	'		'		-15		-7
Payments for short and long-term debt	'		'		-542		-607
Net Cash (Used)/Provided by Financing Activities	'		'		-163		634
Effect of exchange rate changes on cash and cash equivalents	'		'		-24		-2
Net Increase/(Decrease) in Cash and Cash Equivalents	'		'		251		-783
Cash and Cash Equivalents at Beginning of Period	'		'		870		1,258
Cash and Cash Equivalents at End of Period	1,121		475		1,121		475
NRG Energy, Inc.	'		'		'		'
Cash Flows from Operating Activities	'		'		'		'
Net (Loss)/Income	-92		124		-144		-208
Adjustments to reconcile net loss to net cash provided/(used) by operating activities:	'		'		'		'
Depreciation and amortization	5		3		8		6
Net Cash (Used)/Provided by Operating Activities	'		'		-2,429		-844
Cash Flows from Investing Activities	'		'		'		'
Intercompany loans to subsidiaries	'		'		1,360		390
Acquisitions of businesses, net of cash acquired	'		'		-1,792		0
Capital expenditures	'		'		-364		-4
Increase in restricted cash, net	'		'		1		1
Increase in restricted cash - U.S. DOE projects	'		'		-3		-6
Decrease/(increase) in notes receivable	'		'		0		8
Investments in nuclear decommissioning trust fund securities	'		'		0		0
Proceeds from sales of nuclear decommissioning trust fund securities	'		'		0		0
Proceeds from renewable energy grants	'		'		0		0
Proceeds from sale of assets, net of cash disposed of	'		'		77		'
Cash proceeds to fund cash grant bridge loan payment	'		'		0		'
Other	'		'		0		0
Net Cash Provided/(Used) by Investing Activities	'		'		-721		373
Cash Flows from Financing Activities	'		'		'		'
Proceeds from intercompany loans	'		'		1,360		390
Payment of dividends to common and preferred stockholders	'		'		-91		'
Payment of intercompany dividends	'		'		'		-73
Payment for treasury stock	'		'		'		-25
Net (payments for)/receipts from settlement of acquired derivatives that include financing elements	'		'		0		0
Contributions and sale proceeds from noncontrolling interest in subsidiaries	'		'		0		0
Proceeds from issuance of long-term debt	'		'		3,335		477
Proceeds from issuance of common stock	'		'		8		9
Payment of debt issuance costs	'		'		-28		-28
Payments for short and long-term debt	'		'		-2,427		-209
Net Cash (Used)/Provided by Financing Activities	'		'		2,157		541
Effect of exchange rate changes on cash and cash equivalents	'		'		0		0
Net Increase/(Decrease) in Cash and Cash Equivalents	'		'		-993		70
Cash and Cash Equivalents at Beginning of Period	'		'		1,328		751
Cash and Cash Equivalents at End of Period	335		821		335		821
Eliminations	'		'		'		'
Cash Flows from Operating Activities	'		'		'		'
Net (Loss)/Income	-144	[1]	-223	[1],[2]	-314	[1],[3]	-58	[1]
Adjustments to reconcile net loss to net cash provided/(used) by operating activities:	'		'		'		'
Depreciation and amortization	0	[1]	0	[1]	0	[3]	0	[1]
Net Cash (Used)/Provided by Operating Activities	'		'		1,360	[2]	390	[2]
Cash Flows from Investing Activities	'		'		'		'
Intercompany loans to subsidiaries	'		'		0	[2]	0	[2]
Acquisitions of businesses, net of cash acquired	'		'		0	[2]	0	[2]
Capital expenditures	'		'		0	[2]	0	[2]
Increase in restricted cash, net	'		'		0	[2]	0	[2]
Increase in restricted cash - U.S. DOE projects	'		'		0	[2]	0	[2]
Decrease/(increase) in notes receivable	'		'		0	[2]	0	[2]
Investments in nuclear decommissioning trust fund securities	'		'		0	[2]	0	[2]
Proceeds from sales of nuclear decommissioning trust fund securities	'		'		0	[2]	0	[2]
Proceeds from renewable energy grants	'		'		0	[2]	0	[2]
Proceeds from sale of assets, net of cash disposed of	'		'		0	[2]	'
Cash proceeds to fund cash grant bridge loan payment	'		'		0	[2]	'
Other	'		'		0	[2]	0	[2]
Net Cash Provided/(Used) by Investing Activities	'		'		0	[2]	0	[2]
Cash Flows from Financing Activities	'		'		'		'
Proceeds from intercompany loans	'		'		-1,360	[2]	-390	[2]
Payment of dividends to common and preferred stockholders	'		'		0	[2]	'
Payment of intercompany dividends	'		'		'		0	[2]
Payment for treasury stock	'		'		'		0	[2]
Net (payments for)/receipts from settlement of acquired derivatives that include financing elements	'		'		0	[2]	0	[2]
Contributions and sale proceeds from noncontrolling interest in subsidiaries	'		'		0	[2]	0	[2]
Proceeds from issuance of long-term debt	'		'		0	[2]	0	[2]
Proceeds from issuance of common stock	'		'		0	[2]	0	[2]
Payment of debt issuance costs	'		'		0	[2]	0	[2]
Payments for short and long-term debt	'		'		0	[2]	0	[2]
Net Cash (Used)/Provided by Financing Activities	'		'		-1,360	[2]	-390	[2]
Effect of exchange rate changes on cash and cash equivalents	'		'		0	[2]	0	[2]
Net Increase/(Decrease) in Cash and Cash Equivalents	'		'		0	[2]	0	[2]
Cash and Cash Equivalents at Beginning of Period	'		'		0	[2]	0	[2]
Cash and Cash Equivalents at End of Period	$0	[2]	$0	[2]	$0	[2]	$0	[2]
[1]	(a)All significant intercompany transactions have been eliminated in consolidation.
[2]	All significant intercompany transactions have been eliminated in consolidation.
[3]	(a)All significant intercompany transactions have been eliminated in consolidation.NRG ENERGY, INC. AND SUBSIDIARIESCONDENSED CONSOLIDATING STATEMENTS OF OPERATIONSFor the Six Months Ended June 30, 2014 (Unaudited) Guarantor Subsidiaries Non-Guarantor Subsidiaries NRG Energy, Inc. (Note Issuer) Eliminations(a) Consolidated (In millions)Operating Revenues Total operating revenues$4,793 $2,380 $— $(66) $7,107Operating Costs and Expenses Cost of operations3,841 1,736 7 (34) 5,550Depreciation and amortization409 304 8 — 721Selling, general and administrative211 139 144 — 494Acquisition-related transaction and integration costs— 8 44 — 52Development activity expenses— 17 23 — 40Total operating costs and expenses4,461 2,204 226 (34) 6,857Gain on sale of assets— 19 — — 19Operating Income/(Loss)332 195 (226) (32) 269Other Income/(Expense) Equity in earnings/(loss) of consolidated subsidiaries101 (6) 180 (275) —Equity in earnings of unconsolidated affiliates10 18 — (7) 21Other income, net4 8 5 (1) 16Loss on debt extinguishment— (9) (72) — (81)Interest expense(11) (227) (292) 1 (529)Total other income/(expense)104 (216) (179) (282) (573)Income/(Loss) Before Income Taxes436 (21) (405) (314) (304)Income tax expense/(benefit)110 (6) (261) — (157)Net Income/(Loss)326 (15) (144) (314) (147)Less: Net income attributable to noncontrolling interest— 36 9 (39) 6Net Income/(Loss) attributable to NRG Energy, Inc.$326 $(51) $(153) $(275) $(153)(a)All significant intercompany transactions have been eliminated in consolidation.